Infield Rigs News

20 Jul 2017

Noble Energy Terminates the Contract for the Atwood Advantage

Noble Energy has chosen to terminate the contract on the Atwood Advantage drillship. The rig is currently nearing completion of the Leviathan 5 appraisal and production well, offshore Israel. Following a recent tender, Noble Energy and its partners identified the opportunity to hire an alternative rig at a significantly lower day rate. Consequently, Noble has chosen to end the contract for .... [+ read more] the Atwood Advantage on completion of the Leviathan 5 well, and continue the drilling programme with an alternative rig.

14 Jul 2017

Further Delay for New Build Jackup

KS Energy and COSCO Nantong shipyard have agreed to further delay the delivery of the new build jackup rig, the KS Orient Star 2 (hull no. N408). Following an earlier delay the rig was scheduled to be delivered on 31 December 2017. However, the latest agreement has postponed delivery by a further two years to 31 December 2019. .... [+ read more]

12 Jul 2017

53/6-A Well Starts Drilling on the Porcupine Basin

Providence Resources has announced that the 53/6-A exploration well on the FEL 2/14 license began drilling on the 11 July. The well is being drilled by the Stena IceMax harsh environment drillship. .... [+ read more]

12 Jul 2017

Maersk Interceptor to drill on the Hyrokkin Prospect

Aker BP has received consent from Norway's Petroleum Safety Authority (PSA) to drill two wells on the Hyrokkin prospect. The wells, designated 25/4-11 and 25/4-12 will be drilled by the Maersk Interceptor harsh environment jackup. .... [+ read more]

10 Jul 2017

Oyo-9 Drilling Update

Erin Energy has provided an update for the Oyo-9 development well to be drilled offshore Nigeria. The Pacific Bora is now expected to mobilise to location and spud the well by the end of July. According to Erin Energy, Pacific Drilling has confirmed that the Pacific Bora will be ready for deployment. The contract on the Pacific Bora includes one .... [+ read more] firm well and two optional exploration wells. The day rate for the rig is US$195k/day.

7 Jul 2017

Delivery Delay for the West Rigel

North Atlantic Drilling (NADL) has amended an agreement with Jurong Shipyard which will see delivery date for the West Rigel semisub pushed back to 6 January 2018. Both parties will continue to explore commercial opportunities for the rig during the deferral period. In the event that no contract is secured and no alternative transaction is executed, NADL and Jurong will form .... [+ read more] a joint ownership company for the rig, owned 23% by NADL and 77% by Jurong.

6 Jul 2017

Sevan Developer Delivery Deferral

Sevan Drilling has announced that is has amended the delivery deferral period for the Sevan Developer cylindrical drilling unit. The rig is now scheduled to be delivered from the COSCO shipyard on the 30 June 2020. Sevan will continue to market the rig during the deferral period. .... [+ read more]

6 Jul 2017

Safety Clearence for Wisting

OMV has received safety clearance from the Petroleum Safety Authority (PSA) to drill the 7324/8-3 well on the Wisting Central 3 prospect. OMV will use the Island Innovator to drill the well. Drilling is expected to start during mid-August and will take around 31 days to drill. The well was initially due to last 47 days when OMV submitted its application .... [+ read more] to the Environment Agency, however this has since been revised down.

3 Jul 2017

Kick-off for Statoil’s UK exploration campaign

Statoil will soon commence a three-well exploration drilling campaign on the UK continental shelf. In early July, the Transocean Spitsbergen semi-submersible rig will spud the first well in the campaign. “This is an exciting campaign testing three very different opportunities on the UKCS. We hope to make discoveries that can add value to existing projects and also provide the resources necessary .... [+ read more] for new developments on the UKCS,” says Jenny Morris, vice president Exploration, UK. The wells will be drilled in a continuous campaign that is expected to last approximately 2-3 months. The first well, Mariner Segment 9, could prove additional resources and increase the extent of the Mariner Field. After completing the well, expected to take between 15 and 25 days, the rig will move to Jock Scott, a prospect on the underexplored margins of the Viking Graben. The well is expected to be completed in 20-40 days. The last well of the campaign will be the Verbier opportunity in the Moray Firth area. The well is assumed to take 30-70 days to complete. “We have three exciting wells to test with a proven and efficient rig that will enable us to continue to develop our understanding of the full exploration potential of this mature basin and hopefully add new commercial reserves to our UK portfolio,” says Morris.

2 Jul 2017

Contract Termination for ther Bolette Dolphin

Dolphin Drilling Ltd, a subsidiary of Fred. Olsen Energy ASA, has received a termination for convenience notice from Anadarko Petroleum Corporation for the contract for the drilling unit Bolette Dolphin. The termination will be effective at end August 2017. The termination fee will be approximately USD 96 million as per contract. .... [+ read more]

30 Jun 2017

Statoil receives consent for exploration drilling in the Barents Sea

Statoil has received consent to drill an exploration well in block 7435/12 in the Barents Sea. 30.06.2017 Print Tip someone Register for news The well is to be drilled in a prospect named Korpfjell in block 7435/12 in the Barents Sea. The drilling site is in the northern sector of the Barents Sea South-East area, 37 kilometres from .... [+ read more] the Russian boundary and 415 kilometres from the Norwegian mainland. Water depth at the site is 253 metres. The drilling is estimated to last for 30 days, starting in late June. The well is to be drilled by Songa Enabler, which is a semi-submersible mobile drilling facility of the CAT D type. Songa Enabler was delivered by the Daewoo yard in South Korea in 2016, and is owned and operated by Songa Offshore. The facility is registered in Norway and classified by DNV GL. Songa Enabler was issued with an Acknowledgement of Compliance (AoC) by the PSA in July 2016.

28 Jun 2017

Consent for exploration drilling using Leiv Eiriksson

Lundin is the operator of production licence 609. The licence covers block 7220/6 which is around 190 km from Bjørnøya. Drilling will begin in July 2017 and last approx. 34 days, depending on whether a discovery is made. The well is to be drilled by Leiv Eiriksson, which is a semi-submersible drilling facility of the SS Trosvik Bingo 9000 type, .... [+ read more] owned by Ocean Rig and operated by Rig Management Norway. Leiv Eiriksson was issued with an Acknowledgement of Compliance (AoC) by the PSA in July 2008.

26 Jun 2017

Maersk Convincer takes over contract from Maersk Completer

Jack-up Maersk Convincer, currently finalising its five-yearly Special Period Survey (SPS) yard stay in Singapore, will be taking over a contract from its sister rig, the Maersk Completer, currently operating offshore Brunei. The Maersk Completer is on contract with Brunei Shell Petroleum, and has been since November 2008. Before long, the Rig is scheduled to have its five-yearly Special Periodic .... [+ read more] Survey (SPS) yard stay, which means that operations for Brunei Shell Petroleum would have to be suspended while Maersk Completer conducts the yard stay, resulting in a delay in the drilling programme of about 45-60 days. In order to limit impact to the customer’s drilling programme, and to reduce cost for both parties, Maersk Drilling is re-activating the warm-stacked Maersk Convincer, an identical Baker Marine 375ft jack-up. Maersk Convincer is currently finalising its own five-yearly SPS yard stay, and will be ready to leave for the field and take on the remainder of the work scope in August 2017. “Our number one priority is to deliver the safest and most efficient drilling operations to our customers. This also means limiting any interruptions to their programmes, resulting in costly delays. Therefore, following a close dialogue with Brunei Shell Petroleum, we have agreed to put Maersk Convincer in operation for the remainder of the contract,” says Peter Dansen, Vice President and Asset Manager for International Jack-Ups in Maersk Drilling. The current contract is scheduled to end in October 2018, however, Brunei Shell Petroleum have options to extend the contract up to a total of three years. Maersk Convincer will take over operations once Maersk Completer has finalised current batch drilling operations.

20 Jun 2017

Consent to use Bideford Dolphin on the Snorre field

Statoil Petroleum AS has received consent to use the Bideford Dolphin drilling facility for drilling and completing well 34/7-A-10 on the Snorre field. Drilling is scheduled to begin on 7 July 2017 and to last 110 days. Bideford Dolphin is operated by Dolphin Drilling AS. Bideford Dolphin is a mobile drilling facility of the Aker H-3 type, built at Aker .... [+ read more] Verdal in 1975 and modified in 1998. The facility is classified by DNV GL and registered in Singapore. Bideford Dolphin was issued with an Acknowledgement of Compliance (AoC) by the PSA in September 2004.

19 Jun 2017

Dry well west of the Volund field in the North Sea – 24/9-11 S

Aker BP ASA, operator of production licence 150 B, has completed the drilling of wildcat well 24/9-11 S. The well was drilled about 7 kilometres west of the Volund field, 11 kilometres southwest of the Alvheim field and 230 kilometres northwest of Stavanger in the central part of the North Sea. The objective of the well was to prove petroleum .... [+ read more] in Upper Palaeocene reservoir rocks (the Hermod formation). Well 24/9-11 S encountered a 7-metre thick sandstone layer with very good reservoir properties. Some thin, partially cemented sandstone layers were also encountered above the main reservoir, with partially good reservoir properties. The sandstones have been interpreted as being remobilised from the Hermod formation and injected into the overlying Balder formation. The reservoir rocks have only faint traces of oil. The well is classified as dry. Data acquisition and sampling were carried out. This is the first exploration well in production licence 150 B. The licence was awarded in APA 2010. Well 24/9-11 S was drilled to measured and vertical depths of 2211 and 2114 metres below the sea surface, respectively, and was terminated in the Palaeocene Sele formation. The water depth is 122 metres. The well has now been permanently plugged and abandoned. Well 24/9-11 S was drilled by the Transocean Arctic drilling facility, which will now proceed to drill observation well 24/6-A-6 H in production licence 088 BS on the Alvheim field, where Aker BP is the operator.

15 Jun 2017

Statoil receives consent for exploration drilling in the Barents Sea

Statoil has received consent to drill an exploration well in block 7325/4 in the Barents Sea. Well 7325/4-1 ("Gemini Nord") is in the Hoop area in the Barents Sea, around 275 kilometres from Nordkapp and 200 kilometres from Bjørnøya (Bear Island). Water depth at the site is 447 metres. The drilling is estimated to last for 19 days, and is .... [+ read more] scheduled to start in June. The well is to be drilled by Songa Enabler, which is a semi-submersible mobile drilling facility of the CAT D type. Songa Enabler was delivered by the Daewoo yard in South Korea in 2016, and is owned and operated by Songa Offshore. The facility is registered in Norway and classified by DNV GL. Songa Enabler was issued with an Acknowledgement of Compliance (AoC) by the PSA in July 2016.

7 Jun 2017

Statoil receives consent for exploration drilling in the Norwegian Sea

Statoil has received consent to drill an exploration well in block 6507/8 in the Norwegian Sea. The well is to be drilled in a prospect named Carmen in block 6507/8 at Haltenbanken. The site is 222 kilometres west of Brønnøysund in Nordland county and 10 kilometres north-east of Heidrun. A pilot well will be drilled first, down to 800 metres, to .... [+ read more] investigate if there is shallow gas in the area. Water depth at the site is 358 metres. The drilling is estimated to last for 18 days, and will begin in mid-June. The well is to be drilled by Deepsea Bergen, which is a semi-submersible drilling facility of the Aker H-3.2 type, built at Aker Verdal in 1983. It is owned and operated by Odfjell Drilling. It is classified by DNV GL and registered in Norway. Deepsea Bergen was issued with an Acknowledgement of Compliance (AoC) by the PSA in December 2001.

2 Jun 2017

Naga 2 Spuds Ophir Wells

Octanex has spudded the first of the three planned production well son the Ophir development, offshore Malaysia. Ophir A1 was spudded by UMW Naga 2 on June 2nd. THe Ophie field will be developed via three production wells, a well head platform and an FPSO. .... [+ read more]

1 Jun 2017

Stena Drilling cancels newbuilding construction contract for semi-sub Stena MidMAX

Stena Atlantic Ltd, an affiliate of Stena Drilling Ltd, has today notified the Korean shipbuilder, Samsung Heavy Industries Co Ltd (SHI), that it has exercised its right to cancel their contract for the construction of “Stena MidMAX”, a dynamically positioned harsh environment semisubmersible drilling unit. The rig was ordered in June 2013 with a delivery date in March 2016. SHI .... [+ read more] has, however, been unable to complete and deliver the unit within the contractually agreed timeframe. Under the contract terms, Stena Atlantic is entitled to reimbursement of $215.4 million in pre-delivery instalments paid to SHI, plus accrued interest. Stena Atlantic is also intending to pursue claims for compensation in respect of its costs incurred in relation to the project.

31 May 2017

Further Delivery Delay for Sevan Developer

Sevan Drilling has further delayed the delivery date of its Sevan Developer cylindrical semisub. The rig is now due to be delivered from the Cosco Nantong shipyard on the 30th June 2017. The rig was originally due to be delivered in the third quarter of 2014 but the market down turn has seen Sevan push this to the right on several .... [+ read more] occasions.

31 May 2017

Aker BP receives consent to use Transocean Arctic at Alvheim

Aker BP has received consent to use Transocean Arctic to drill two production wells on the Alvheim field. The two wells are designated 24/6-A-6 and 24/6-A-7 and are to be drilled in Boa, which is one of the four reservoirs comprising the Alvheim field. Transocean Arctic is a semi-submersible mobile drilling facility of the Marosso 56 type, built by Mitsubishi .... [+ read more] Heavy Industries in Japan in 1987. It was upgraded in 2004, is classified by DNV GL and registered in the Marshall Islands. The facility is operated by Transocean Ltd. It was issued with an Acknowledgement of Compliance (AoC) by the PSA in July 2004.

30 May 2017

Eni receives consent to use Scarabeo 8 at Goliat

Eni has received consent to use Scarabeo 8 at Goliat. The facility will drill two production wells. One of the two wells to be drilled is for oil production, while the other is for water injection. A pilot hole will be drilled first and the production well drilled as a sidetrack from this. Horizontal drilling will be used and the .... [+ read more] well has been designated 7122/7-C-1 AH. The water injection well has been designated 7122/7-H-2 H and this will entail directional drilling. Drilling is scheduled to begin on 24 June 2017. The wells are to be drilled by Scarabeo 8, which is a mobile drilling facility of the Moss CS50 MKII type, operated by Saipem Norge. It was built in Russia and Italy and commissioned in 2012. The facility is classified by DNV GL and registered in the Bahamas. Scarabeo 8 was issued with an Acknowledgement of Compliance (AoC) by the PSA in May 2012.

26 May 2017

FAN South-1 Well Spud

The Cairn operated FAN South-1 exploration well has commenced drilling. The well is being drilled in 2,139 meters of water to an expected total depth of 5,317 meters below the mudline. The Stena Drillmax drillship is completing the well. .... [+ read more]

25 May 2017

Brasse Appraisal Well Spuds

Faroe Petroleum has announced that the Brasse appraisal well (well number 31/7-2S) has commenced drilling. The Brasse field was discovered in licence PL740 in July 2016. The primary objectives of the appraisal well are to reduce uncertainty in the reserve estimates and provide more information for the development project. According to Faroe, a decision on a second Brasse appraisal well will .... [+ read more] be made later this year. The well is being drilled by Odfjell Drilling's Deepsea Bergen semisub.

24 May 2017

Hyperdynamics commences drilling operations in Guinea on the back of amended contract with Pacific Drilling

Hyperdynamics Corporation (OTCQX: HDYN) today announced that on May 21, 2017 the Pacific Scirocco drillship entered Guinea shelf waters and is commencing drilling operations as provided by the Third Amendment to the Production Sharing Contract ("PSC"), signed by the Republic of Guinea Government on April 12, 2017 and approved by President Alpha Conde on April 21, 2017. Last .... [+ read more] week, SCS Corporation, the wholly owned subsidiary of Hyperdynamics Corporation, and Pacific Drilling made effective an amendment to the drilling contract with a subsidiary of Pacific Drilling for the use of the Pacific Scirocco for mobilization for petroleum operations. The Amendment stipulates the rates and timing related to installing on the rig some drilling-related equipment, stocking up materials and supplies for the subsequent spudding of the Fatala 1 well. "We are very pleased that the rig has arrived in Guinea and has commenced drilling operations as provided by the Third Amendment to the PSC and look forward to drilling the Fatala prospect as soon as the rig gets on board additional equipment and supplies. We highly value our business relationship with both SAPETRO and Pacific Drilling," said Hyperdynamics President and Chief Executive Officer Ray Leonard.

22 May 2017

Zama-1 Spudded

Premier is pleased to announce that the Zama-1 exploration well in Block 7 (Premier equity 25 per cent) in the shallow water Sureste Basin, offshore Mexico, was spudded at 0630 on 21 May 2017. This is the first exploration well to be drilled on acreage awarded in Mexico’s first international licencing round in 2015. The well’s principal target is .... [+ read more] the low risk Zama prospect with supportive direct hydrocarbon indicators in the Tertiary clastic reservoirs. The Zama structure is estimated to have a P90-P10 gross unrisked resource range of 100-500 mmbbls. The well is expected to take up to 90 days to drill both the Zama prospect and the secondary target, Zama Deep, at a total cost to Premier of $16 million. The partners in Block 7 are Talos Energy (operator, 35 per cent), Sierra Oil and Gas (40 per cent) and Premier (25 per cent).

22 May 2017

Consent to use Bideford Dolphin at Vigdis

Statoil has received consent to use the Bideford Dolphin mobile drilling facility for production drilling at Vigdis. Statoil is to plug the B-1 AH production well on the Vigdis field. Using a sidetrack from this well, a new well is to be drilled, B-1 BH. The activities are to be undertaken using Bideford Dolphin, which is operated by Dolphin Drilling .... [+ read more] AS. Bideford Dolphin is a semi-submersible drilling facility of the Aker H-3 type, built at Aker Verdal in 1975 and modified in 1998. The facility is classified by DNV GL and registered in Singapore. Bideford Dolphin was issued with an Acknowledgement of Compliance (AoC) by the PSA in September 2004.

18 May 2017

Senegal SNE-6 Appraisal Well result

Cairn is pleased to announce the results of another successful appraisal well offshore Senegal. Rig performance continues to be excellent and operations have been safely and successfully completed ahead of schedule and under budget following drilling, logging and drill stem testing (DST). The objective of the SNE-6 well, together with the previous successful SNE-5 well, was to flow oil from .... [+ read more] one of the principal units in the upper (400 series) reservoirs and demonstrate connectivity between the two wells. Pressure data from SNE-6 immediately confirmed good connectivity with SNE-5 and accordingly a short DST was performed. SNE-6 is being plugged and abandoned and the Stena DrillMAX drill ship is moving location to commence operations at the FAN SOUTH exploration well, ~20km south west of the SNE-3 well in ~2,175m water depth. FAN SOUTH is targeting a mean prospective resource of more than 110 mmbbls with dual prospects; an Upper Cretaceous stacked multi-layer channelized turbidite fan prospect and a Lower Cretaceous base of slope turbidite fan prospect, which is equivalent to the FAN-1 2014 oil discovery.

18 May 2017

Keppel on track to deliver state-of-the-art drilling rig in Azerbaijan

Keppel Offshore & Marine Ltd (Keppel O&M) through its subsidiary in Azerbaijan, Caspian Shipyard Company (CSC), is on track to deliver a semisubmersible drilling rig to Caspian Drilling Company Ltd, a subsidiary of the State Oil Company of Azerbaijan Republic (SOCAR). The rig was named Heydar Aliyev at a ceremony in Azerbaijan today by the President of Azerbaijan, Ilham Aliyev. .... [+ read more] Built to Keppel FELS' proprietary DSSTM 38M design, the rig has been customised for the Caspian Sea's harsh environment condition. It is the first modern semisubmersible to be almost completely built in Azerbaijan.

17 May 2017

Topaz on Location at Bualuang

The Topaz driller is now on location at the Bualuang field, offshore Thailand. The rig will be used to drill two infill development wells and one well targeting a near-field prospect. According to an Ophir update, the three wells will be completed at a cost of US$12m. Current production (year to date) from Bualuang is averaging 8,100 barrels per day. .... [+ read more]

15 May 2017

Ayame-1X Well Result

Ophir announces that the Ayame-1X exploration well in Block 513, Cote D’Ivoire, has reached total depth of 5,394m True Vertical Depth Sub Sea. The well was targeting a number of turbidite channel complexes of Santonian and Turonian age. The prospective reservoir intervals were encountered as prognosed. Oil shows were recorded in the target reservoirs, but significant hydrocarbons were not encountered. To .... [+ read more] date the operation has been conducted without incident, having successfully drilled and cased the longest riser-less surface section in the region and reached TD in the subsequent hole section with a single bit run (another basin first). Operations are forecast to complete by the 22nd May at an estimated final cost of $20.5 million gross. Full analysis and interpretation of the data is ongoing, but the well will be plugged and abandoned as a dry hole. Ophir has a 45% operated interest in Block 513.

15 May 2017

Consent to use Mærsk Invincible at Valhall

Aker BP has received consent to use Mærsk Invincible for plugging wells at Valhall. The consent applies to the use of Maersk Invincible for permanent plugging of wells drilled from the DP. Production from Valhall DP is scheduled to end in the next few years. Three of the wells are still in production, while 18 have been shut down. Of .... [+ read more] these, 13 have been permanently plugged and abandoned, and Maersk Invincible will be used for plugging the other five. Maersk Invincible is a jack-up drilling facility owned by Maersk Drilling, Denmark. It was delivered by the Daewoo yard in South Korea in 2016, is classified by DNV GL and registered in Singapore.

12 May 2017

Dry well west of the Aasta Hansteen field in the Norwegian Sea – 6705/7-1

Repsol Norge AS, operator of production licence 705, has completed the drilling of wildcat well 6705/7-1. The well was drilled about 80 kilometres northwest of the Aasta Hansteen field in the northern part of the Norwegian Sea. The objective of the well was to prove petroleum in Upper Cretaceous reservoir rocks (Nise formation). Well 6705/7-1 encountered two reservoir intervals .... [+ read more] with a total thickness of about 200 metres of sandstone in the Nise formation with good to moderate reservoir quality. The reservoir rocks only contain weak traces of gas. The well is classified as dry. Data acquisition and sampling were carried out. This is the first exploration well in production licence 705. The licence was awarded in the 22nd licensing round in 2013. Well 6705/7-1 was drilled to a vertical depth of 3250 metres below the sea surface and was terminated in the Nise formation in the Upper Cretaceous. Water depth at the site is 1404 metres. The well has now been permanently plugged and abandoned. Well 6705/7-1 was drilled by the Transocean Spitsbergen drilling facility. Following a short break, the rig will proceed to the UK shelf to drill three wells for Statoil.

11 May 2017

Alta Appraisal Well Spudded

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that its wholly owned subsidiary Lundin Norway AS (Lundin Norway) has commenced drilling of appraisal well 7220/11-4 (Alta-4) on the Alta discovery in PL609, located on the Loppa High in the southern Barents Sea. The Alta-4 well is located approximately 2 km south of the original discovery well 7220/11-1 and is .... [+ read more] the fourth well to be drilled on the Alta discovery. The main objective of the Alta-4 well is to further appraise the Alta discovery and to provide a calibration point for the drilling of a horizontal well for a possible extended well test that is being planned for 2018. The Alta discovery is estimated to contain gross contingent resources of between 125 and 400 million barrels of oil equivalents (MMboe). The Alta-4 well will be drilled by the semi-submersible drilling rig Leiv Eiriksson and is expected to take approximately 65 days. Lundin Norway is the operator of PL609 with a 40 percent working interest.

10 May 2017

Rowan Highest Bidder for Petrobras Jackups

Rowan Companies plc, through a wholly owned subsidiary, participated in the recent Petrobras public rig auction and was the high bidder for P-59 and P-60, two 2013 built LeTourneau Super 116E jack-up rigs.  While Rowan was the high bidder and is required to purchase the rigs at its bid price (US$30 million per rig), the auction results have not yet been approved by Petrobras. .... [+ read more]

10 May 2017

Brasse Appraisal Well Consent

Faroe Petroleum, the independent oil and gas company focusing principally on exploration, appraisal and production opportunities in Norway, the UK and Atlantic Margin, is pleased to announce that all relevant consents have been received for the drilling of an appraisal well 31/7-2S on the Brasse discovery (Faroe 50%). Faroe, as operator has entered into a contract with Odfjell Drilling for .... [+ read more] the use of the semi-submersible drilling rig, Deepsea Bergen, for the drilling operations which are expected to commence before the end of this month with the earliest spud date being on or around 18 May 2017. The Brasse discovery is located within tie-back distance to existing infrastructure: 13 kilometres to the south of the Brage field platform, in which the Company holds a 14.3% working interest and 13 kilometres to the south east of the Oseberg Field Centre. The co-venturer in the Brasse licence PL740 Faroe is Point Resources AS (50%).

9 May 2017

Audit of Transocean Arctic

We have carried out an audit of Transocean Arctic in respect of structural safety. On 4 and 5 April 2017, we carried out an audit of the Transocean Arctic mobile drilling facility in the domain of structural safety. The audit was conducted at Transocean's premises at Forus in Stavanger and addressed primarily robustness, lifecycle challenges and barriers within structures and .... [+ read more] marine systems, as well as analyses of waves on deck. The audit is founded on our main theme for 2017 – "Reversing the trend" – and in particular on the pillar of robustness. During the audit, we focused on robustness in the context of ageing mechanisms. Transocean Arctic was built in 1984 and upgraded in 2004. The facility received Acknowledgement of Compliance (AoC) in July 2004. No regulatory non-conformities were detected during the audit, though a handful of improvement points were identified. Transocean has been asked to report on how these improvement points will be assessed by 19 May 2017.

9 May 2017

Octanex Awaiting Naga 2

Octanex has announced that it expects the Naga 2 jackup to be handed over from its previous contract with Vestigo between the third and fourth week of May 2017. Following handover, the rig will be towed to the Ophir field offshore Malaysia where it will complete a three well development drilling programme. The first well is expected to spud towards the .... [+ read more] end of May.

8 May 2017

Lundin receives consent for exploration drilling in the Barents Sea

Lundin has received consent to drill an exploration well in block 7220 in the Barents Sea. Lundin is the operator for production licence 609 in the Barents Sea. We have given the company consent to drill exploration well 7220/11-4 in a prospect named Alta. Drilling is scheduled to begin in May 2017 and will last 65 days. Possible well .... [+ read more] testing will be in addition. Water depth at the site is 402 metres. The well is to be drilled by Leiv Eiriksson, which is a semi-submersible drilling facility of the BINGO 9000 type, owned and operated by Ocean Rig ASA. It was built in China in 2001 and fitted out in the USA. Leiv Eiriksson was issued with an Acknowledgement of Compliance by the PSA in July 2008.

8 May 2017

Statoil receives consent to use Songa Encourage at Troll

Statoil has received consent to use Songa Encourage for drilling and completing a production well on the Troll field. We have given Statoil consent to use the Songa Encourage mobile drilling facility to drill and complete production well 31/2-O-24 on the Troll field. The well is to be drilled in a well template tied back to Troll C by a .... [+ read more] subsea pipeline. Water depth at the site is 338 metres. The drilling work is scheduled to take 71 days. Songa Encourage is a semi-submersible drilling facility of the GVA 4000 type, operated by Songa Offshore. It was built at the Daewoo yard in South Korea in 2016. It is classified by DNV GL and registered in Norway. Songa Encourage was issued with an Acknowledgement of Compliance (AoC) by the PSA in April 2017.

8 May 2017

Next Well for the Murmanskaya Jackup

The Murmanskaya jackup has completed well 12/11-TN-3X and has moved onward to well number 12/11-EF- 1X. The well will be drilled to 4,723m. Drilling will take approximately 113 days. .... [+ read more]

8 May 2017

Driling on Blocl PM3, North Bunga Orkid 4, offshore Terengganu

Repsol will drill an exploration well on Block PM3, North Bunga Orkid 4, offshore Terengganu. The operator currently has the rig on sublet from Murphy Oil. According to the local authorities the well will be drilled between 15th May and 15th August 2017. The Ensco 52 is chartered by Murphy Oil from Ensco at a day rate of US$98k. The rate .... [+ read more] agreed between Murphy and Repsol has not been disclosed.

4 May 2017

Transocean Spitsbergen Completes Repsol Contract

Repsol has completed drilling the 6705/7-1 exploration well on production licence 705. The well was drilled by the Transocean Spitsbergen and was spudded in March 2017. The Transocean Spitsbergen has demobilised from the drill site and is currently laid-up in Norway. The rig is due to move to the UKCS to drill three exploration wells for Statoil on the Mariner, .... [+ read more] Jock Scott and Verbier licenses.

4 May 2017

Bolette Dolphin Completes Gorgon-1 in Colombia

The Bolette Dolphin has completed its two well exploration campaign in Colombia for Anadarko and is now mobilising back to West Africa. The rig will remain under contract with Anadarko until July 2018. .... [+ read more]

4 May 2017

Drilling permit for well 31/7-2 S in production licence 740

The Norwegian Petroleum Directorate has granted Faroe Petroleum Norge AS a drilling permit for well 31/7-2 S, cf. Section 8 of the Resource Management Regulations. Well 31/7-2 S will be drilled from the Deepsea Bergen drilling facility, at position 60°24'18.17"N and 3°2'23.75"E in production licence 740. The drilling programme for well 31/7-2 S relates to the drilling of an .... [+ read more] appraisal well. Faroe Petroleum Norge AS is the operator with an ownership interest of 50 per cent, and Core Energy AS is a licensee with 50 per cent. The area in this licence constitutes a part of blocks 31/7 and 30/9. Production licence 740 was awarded in APA 2013, 7 February 2014. This is the third well to be drilled in the licence. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

3 May 2017

Acknowledgement of Compliance for Maersk Invincible

On 11 April 2017, Maersk Drilling Norge AS received the PSA's Acknowledgement of Compliance for Maersk Invincible. Maersk Invincible is a jack-up drilling facility of the XLE type, built at the DSME yard in Busan, South Korea in 2016. .... [+ read more]

3 May 2017

Delineation of oil and gas discovery 7120/1-3 (Gohta) in the Barents Sea – 7120/1-5

Lundin Norway AS, operator of production licence 492, is about to complete the drilling of appraisal well 7120/1-5 on the oil and gas discovery 7120/1-3 (Gohta). The well was drilled about four kilometres north of the discovery well, about three kilometres east of appraisal well 7120/1-4 S, which was drilled in 2014, and about 17 kilometres southwest of the discovery 7220/11-1 .... [+ read more] (Alta). The discovery was proven in 2013 in Permian carbonate rocks . Before well 7120/1-5 was drilled, the resource estimate for the discovery was between 10 and 21 million standard cubic metres (Sm3) of recoverable oil and between 5 and 8 billion standard cubic metres (Sm3) of recoverable gas. The objective of the well was to delineate the northern part of the discovery 7120/1-3 (Gohta) and to investigate the reservoir quality in Permian carbonate rocks and Permian-Triassic conglomerates. Well 7120/1-5 encountered about 300 metres of carbonates in the Røye formation with poor reservoir quality. Pressure gradients were not established and the forecasted Permian-Triassic conglomerates were not encountered. The well is classified as dry, with traces of hydrocarbons. The well has not been formation tested, but extensive data acquisition and sampling have been conducted. The resource estimate for the discovery will be reduced as a result of the well. An updated resource estimate will be prepared during the year based on all new data. Development of the Gohta discovery is being considered along with the 7220/11-1 (Alta) discovery. The well result will not have any impact on the operator’s plans for further delineation of the Alta discovery. This is the third exploration well in production licence 492. The licence was awarded in APA 2007. Well 7120/1-5 was drilled to a vertical depth of 2502 metres below the sea surface and was terminated in the Røye formation in Permian. Water depth is 344 metres. The well will be permanently plugged and abandoned. The well was drilled by the Leiv Eiriksson drilling facility, which will now proceed to drill appraisal well 7220/11-4 in production licence 609 in the Barents Sea, where Lundin Norway AS is the operator.

2 May 2017

HYSY 982 Launched in China

Dalian Shipbuilding Industry Offshore has launched COSL's newbuild semisub rig, the Hai Yang Shi You 982. The rig is slated for delivery in Q4 this year / Q1 next year. The rig's work programme is yet to be announced. The HYSY 982 was ordered in October 2013 and is capable of drilling in 1,500 meters of water. .... [+ read more]

2 May 2017

Deepsea Metro I to Demobilise from Galoc Well

Nido Petroleum Limited (ASX: NDO) (“Nido” or the “Company”) on behalf of the Galoc Joint Venture advises that as at 1.00 PM (WST) on 2 May 2017 demobilisation of the rig had been completed and the Deepsea Metro I was off-hire to the Galoc Joint Venture partners. .... [+ read more]

2 May 2017

Ayamé-1X Well Spud

African Petroleum is pleased to announce that the Ayamé-1X exploration well, offshore Côte d’Ivoire, was spudded on Saturday 29 April 2017 using the Seadrill West Saturn Drillship. The well, operated by Ophir Energy, is located on the CI-513 licence. African Petroleum holds a 45% interest in the licence, with Ophir Energy holding 45% and PETROCI the remaining 10%. The Ayamé -1X .... [+ read more] well will target Santonian and Turonian turbidite channel complexes through a water depth of 2,835 metres, with planned total depth (“TD”) at 5,459 metres. The well is expected to reach TD in approximately 30 days from spud.

1 May 2017

Galoc-7ST-1 Drilling Results

Nido Petroleum Limited (ASX: NDO) (“Nido” or the “Company”), on behalf of the Galoc Joint Venture, advises that a TD of 2,569 metres MD RT (2,261 metres TVD RT) was reached in Galoc-7ST-1, which is being drilled by the Deepsea Metro I, having drilled through the Galoc Clastic Unit reservoir interval. The Deepsea Metro I is now in the process of .... [+ read more] plugging and abandoning the Galoc-7ST-1 well ahead of demobilising the rig. The objective reservoir interval for the Galoc-7ST-1 well was encountered between 2,412 to 2,561 metres MD RT (2,131 to 2,253 metres TVD RT) with a gross thickness of 122 metres and net reservoir thickness of 12 metres. The net reservoir interval consists primarily of interbedded sandstone and claystone. Preliminary Logging Whilst Drilling (“LWD”) and wireline log data which was recorded through this interval indicates the reservoir unit contains hydrocarbons. At this stage the Galoc-7ST-1 well results, in combination with the Galoc-7 results, are being evaluated by the Company and the results of both wells will be incorporated into the relevant subsurface models to assess the commerciality of a potential Phase III development.

1 May 2017

Seadrill Agrees to Sell Three Jack-ups for $225 million

Seadrill Limited ("Seadrill" or "The Company"), announces that it has reached an agreement with Shelf Drilling to sell the West Triton, West Resolute and West Mischief for a total consideration of $225 million subject to customary closing conditions. The West Triton and West Resolute are scheduled to be delivered to Shelf Drilling by the end of May 2017 and the West .... [+ read more] Mischief during 3Q 2017 after completion of its current drilling contract with NDC in Abu Dhabi. The total debt outstanding on these three units is $102 million providing excess sale proceeds of $123 million. The carrying value of the three units totals $415 million. A loss on disposal of $190 million is expected to be realized for the first quarter of 2017.

1 May 2017

Seadrill Agrees to Sell Three Jack-ups for $225 million

Seadrill Limited ("Seadrill" or "The Company"), announces that it has reached an agreement with Shelf Drilling to sell the West Triton, West Resolute and West Mischief for a total consideration of $225 million subject to customary closing conditions. The West Triton and West Resolute are scheduled to be delivered to Shelf Drilling by the end of May 2017 and the West .... [+ read more] Mischief during 3Q 2017 after completion of its current drilling contract with NDC in Abu Dhabi. The total debt outstanding on these three units is $102 million providing excess sale proceeds of $123 million. The carrying value of the three units totals $415 million. A loss on disposal of $190 million is expected to be realized for the first quarter of 2017.

1 May 2017

Seadrill Agrees to Sell Three Jack-ups for $225 million

Seadrill Limited ("Seadrill" or "The Company"), announces that it has reached an agreement with Shelf Drilling to sell the West Triton, West Resolute and West Mischief for a total consideration of $225 million subject to customary closing conditions. The West Triton and West Resolute are scheduled to be delivered to Shelf Drilling by the end of May 2017 and the West .... [+ read more] Mischief during 3Q 2017 after completion of its current drilling contract with NDC in Abu Dhabi. The total debt outstanding on these three units is $102 million providing excess sale proceeds of $123 million. The carrying value of the three units totals $415 million. A loss on disposal of $190 million is expected to be realized for the first quarter of 2017.

30 Apr 2017

Al Lulu Jackup Delivered

Lamprell (ticker: LAM), a leading provider of diversified engineering and contracting services to the energy industry, announces the completion of construction on the final jackup drilling rig in a series of nine, the “Al Lulu”, and its delivery to Abu Dhabi’s National Drilling Company (“NDC”), within budget and as scheduled. The contract for the NDC “Al Lulu” rig was awarded in .... [+ read more] April 2015, one of only three rig orders awarded that year. All nine rigs have been designed according to the Cameron LeTourneau Super 116E (Enhanced) Class design and were completed to the highest standards of quality using the latest in drilling system technology. Completion and delivery of the jackup rig was marked at an inauguration ceremony held at Lamprell’s Hamriyah facility in the UAE on 27 April and the rig will depart to its drilling location in Abu Dhabi shortly. Rig "Al Lulu" is the 21st 116E jackup drilling unit that Lamprell has delivered since its listing in 2006 and the 28th jackup drilling rig in total.

26 Apr 2017

West Capricorn to Return to Service

BP has notified Seadrill Partners to prepare the West Capricorn for a return to operational service. The West Capricorn semisub was down-manned and placed on extended standby in May 2016. The rig will remain on standby rate until July 1st, 2017. The rig is currently located in the US Gulf. Before being laid-up the rig was working on BP's Constellation (formerly .... [+ read more] Hopkins) discovery.

24 Apr 2017

CHC Wins Contract with Providence Resources PLC

CHC Group (the "Company" or "CHC") today announced it has signed a new contract with Providence Resources plc ("Providence") to provide helicopter services in support of its Exploration well program on the Druid/Drombeg prospect in Frontier Exploration Licence 2/14 of the southern Porcupine Basin, Offshore Ireland, some 215 kilometers off the southwest coast of Ireland. The contract will see a dedicated .... [+ read more] Sikorsky S-92 flying out of Cork Airport beginning this June and will once again see CHC work in conjunction with Lloyd’s Register ("LR") as the wells project management company."We are delighted that Providence and LR have, once again, selected CHC as its aviation partner," said Mark Abbey, CHC Regional Director for Europe, Middle East and Africa (EMEA). "With our extensive experience transporting offshore workers in the oil and gas industry, dedication to safety, and reputation for the highest quality service, we look forward to building on our relationship with the Providence team in Ireland,""This is a great continuation of our relationship with both Providence and LR," added Karl Fessenden, President and CEO of CHC Helicopter. "We look forward to supporting this operation and providing the global standards for safety, logistical support and efficiency that customers around the world expect from CHC."

24 Apr 2017

Delineation of the Edvard Grieg field in the North Sea – 16/1-27

Lundin Norway AS, operator of production licence 338, has completed the drilling of appraisal well 16/1-27 on the Edvard Grieg oil field in the central part of the North Sea. The well was drilled about three kilometres southwest of the Edvard Grieg platform. The field was proven in the autumn of 2007, and consists of Cretaceous and Jurassic/Triassic reservoir rocks. .... [+ read more] Before well 16/1-27 was drilled, the operator’s resource estimate for the field was 35 million standard cubic metres (Sm3) of recoverable oil equivalents. The objective of the well was to investigate the scope of the field, its reservoir properties and total oil column in the southwestern part of the Edvard Grieg field. The objective also included optimising the drainage strategy in order to ensure the best possible placement of development wells in this area. Well 16/1-27 encountered a total oil column of 15 metres in Cretaceous and Triassic/Jurassic sandstone with very good reservoir quality. Overall, the sandstone interval was 94 metres, an increase from 38 metres expected before the well. The oil/water contact was encountered 1948 metres below the sea surface, which is nine metres deeper than the contact in the other part of the Edvard Grieg field. Extensive data acquisition and sampling have been carried out. Preliminary calculations shows that the results from the well can lead to an increase of between 1.6 to 4.8 million standard cubic metres (Sm3) of recoverable oil in this part of the Edvard Grieg field. Further work is expected to reduce the uncertainty in this estimate. The results have provided valuable information with regard to final placement of production and water injection wells. 16/1-27 is the 11th exploration well in production licence 338 and the eighth exploration well on Edvard Grieg. The licence was awarded in APA 2004. Appraisal well 16/1-27 was drilled to a vertical depth of 2229 metres below the sea surface and was terminated in granitic basement. The well has been permanently plugged and abandoned. The well was drilled by the Island Innovator drilling facility.

20 Apr 2017

Statoil receives consent for exploration drilling in the Barents Sea

Statoil has received consent to drill an exploration well in block 7219 in the Barents Sea. Statoil is the operator for production licence 532 in the Barents Sea and has received consent to drill exploration well 7219/9-2 in a prospect named Kayak. The drilling site is 198 kilometres north-west of Sørøya in Finnmark and around 140 kilometres north-west of Goliat. Water .... [+ read more] depth at the site is 336 metres. Drilling is scheduled to begin in April 2017 and is scheduled to last 27 days. The well will be drilled using the Songa Enabler mobile drilling facility, which is owned and operated by Songa Offshore. Songa Enabler is a semi-submersible facility of the CAT D type, built at the Daewoo yard in South Korea in 2016. It is classified by DNV GL and registered in Norway.

11 Apr 2017

Edvard Grieg appraisal well completed

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that its wholly owned subsidiary Lundin Norway AS (Lundin Norway) has completed the Edvard Grieg Southwest appraisal well 16/1-27. The appraisal well 16/1-27 in PL338 on the Edvard Grieg field is located on the southwestern flank of the field targeting additional resources. The well was drilled 3 km west of the Edvard .... [+ read more] Grieg platform. The objective of the well was to appraise the southwestern flank of the field in order to optimise the drainage strategy and to prove additional resources. The well encountered a 15 metres gross oil column in a 94 metres thick sandstone reservoir compared to the pre-drill estimate of 38 metres thickness. The top reservoir was encountered deeper than prognosed with excellent reservoir quality that was better than expected. The oil water contact was encountered at 1,948 metres below mean sea level 9 metres deeper than the established contact in this part of the Edvard Grieg field. Pressure data confirms communication with the Edvard Grieg field. Extensive data acquisition was carried out in the reservoir including conventional coring and fluid sampling. The well results confirm a preliminary resource upside for this part of the Edvard Grieg field in the order of 10 to 30 MMboe. The final implication for total reserves for the Edvard Grieg field will be quantified in the 2017 year end reserves update. The well was drilled using the semi-submersible drilling rig Island Innovator and will be permanently plugged and abandoned. Lundin Norway is the operator of PL338 and holds a 65 percent working interest. The partners are OMV Norge AS with 20 percent and Wintershall Norge AS with 15 percent working interest.

10 Apr 2017

Construction Delay

Northern Offshore Ltd. (“NOF”), a company incorporated and having its registered offices in Bermuda, is currently building two (2) LeTourneau Super 116E jack-up drilling rigs at COSCO (Dalian) Shipyard Company Ltd.’s (“Builder”) shipyard in Dalian, China. NOF wishes to announce that NOF and Builder have mutually agreed to further extend the rig technical acceptance date of its first Rig, Energy .... [+ read more] Engager (Hull No. N610) to the end of September 2017 and the second Rig, Energy Encounter (Hull No. N611) to the end of March 2018. NOF and Builder also agreed to delay contract delivery of the Energy Engager and Energy Encounter until a future date determined by mutual agreement. These extensions were agreed upon taking into account the current unfavourable international oil and gas market conditions.

10 Apr 2017

Construction Delay

Northern Offshore Ltd. (“NOF”), a company incorporated and having its registered offices in Bermuda, is currently building two (2) LeTourneau Super 116E jack-up drilling rigs at COSCO (Dalian) Shipyard Company Ltd.’s (“Builder”) shipyard in Dalian, China. NOF wishes to announce that NOF and Builder have mutually agreed to further extend the rig technical acceptance date of its first Rig, Energy .... [+ read more] Engager (Hull No. N610) to the end of September 2017 and the second Rig, Energy Encounter (Hull No. N611) to the end of March 2018. NOF and Builder also agreed to delay contract delivery of the Energy Engager and Energy Encounter until a future date determined by mutual agreement. These extensions were agreed upon taking into account the current unfavourable international oil and gas market conditions.

7 Apr 2017

Drilling permit for well 24/9-11 S in production licence 150 B

The Norwegian Petroleum Directorate has granted Aker BP ASA a drilling permit for well 24/9-11 S, cf. Section 8 of the Resource Management Regulations. Well 24/9-11 S will be drilled from the Transocean Arctic drilling facility, at position 59°29’6.79’’ north and 01°50’7.65” east. The drilling programme for well 24/9-11 S relates to the drilling of a wildcat well in production .... [+ read more] licence 150 B. Aker BP ASA is the operator with an ownership interest of 65 per cent, while Lundin Norway AS is a licensee with an ownership interest of 35 per cent. Production licence 150 B was awarded in 2011 (APA 2010). The area in this production licence is located in the central part of the North Sea, and consists of parts of block 24/9, which borders on the UK shelf. The well will be drilled southwest of the 24/9-5 Volund field. This is the first well to be drilled within the production licence. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

7 Apr 2017

Drilling permit for wellbore 7121/8-1 in production licence 849

The Norwegian Petroleum Directorate has granted Statoil Petroleum AS a drilling permit for wellbore 7121/8-1, cf. Section 8 of the Resource Management Regulations. Wellbore 7121/8-1 will be drilled from the Songa Enabler drilling facility, at position 71°25'43.86" N and 21°38'26.5" E after completing the drilling of production well 7121/4-F-3 H for Statoil Petroleum AS in production licence PL 099 on the .... [+ read more] Snøhvit field. The drilling programme for wellbore 7121/8-1 relates to the drilling of a wildcat well in production licence 849. Statoil Petroleum AS is the operator with an ownership interest of 50 per cent. The other licensees are Eni Norge AS (30 per cent) and Petoro AS (20 per cent). The area in this licence consists of a small part of block 7121/7 and parts of blocks 7121/8, 7121/9 and 7122/7. The well will be drilled about 25 kilometres southeast of the Snøhvit field. Production licence 849 was awarded on 5 February 2016 in APA 2015. This is the first well to be drilled in the licence area. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

6 Apr 2017

Rig Delivery

Lamprell (ticker: LAM), a leading provider of fabrication, engineering and contracting services to the energy industry, is pleased to announce the completion of the “Shelf Drilling Krathong” jackup drilling rig and its delivery to Shelf Drilling Ltd. (“Shelf Drilling”), on schedule and within budget. The rig will sail within the next few days for deployment by the client at its drilling .... [+ read more] location, offshore Thailand. The Shelf Drilling Krathong rig has been designed and constructed to the same high quality specifications as its sister rig, the “Shelf Drilling Chaopraya”, which was delivered to Shelf Drilling in September 2016. The LeTourneau Super 116E (Enhanced) Class rig features high specification offshore drilling technology, as well as accommodation for up to 160 people.

5 Apr 2017

Vantage Drilling International Announces Acquisition

Vantage Drilling International ("Vantage"), announced today that its subsidiary, Vantage Drilling Africa, has acquired the Hercules 260, a Marathon LeTourneau Class jack-up drilling unit, from Hercules International Drilling, Ltd., a subsidiary of Hercules Offshore, Inc., for an undisclosed amount and has renamed the rig the Vantage 260. As part of the acquisition, Vantage Drilling Africa acquired a multi-year drilling contract with .... [+ read more] ENI Congo. Vantage is reactivating the Sapphire Driller, a Baker Marine Pacific Class 375 jack-up rig currently warm-stacked offshore of the Republic of Congo, and later this year will substitute it for the Vantage 260. Ihab Toma, Vantage's Chief Executive Officer, commented, "We are delighted to have completed this transaction and are happy to welcome the 260 team to Vantage. We look forward to continuing the excellent operations for ENI Congo."

5 Apr 2017

Eni makes a new gas and condensates discovery offshore Libya

Eni has made a new discovery of gas and condensates offshore Libya in the ‘Gamma Prospect‘, in the Contract Area D, 140 km offshore from Tripoli, in Libya. The discovery, made through the well B1 16/3, is located 15km south west of the Bouri field and 5km north of the Bahr Essalam field. The drilling of the Gamma prospect is part .... [+ read more] of the “near field” exploration strategy of Eni, targeting opportunities, that in case of success can exploit synergies with existing infrastructures reducing the time to market and providing additional gas to the local market and export. The well, drilled in 150 metres of water depth, reached a total depth of 2,981 metres (9,780 feet) and encountered gas and condensates in the Metlaoui Group of Eocene age. The well has the capacity to deliver, in production configuration, in ecxess of 7,000 Boepd and represents a further discovery made by Eni in Libyan offshore Area D, following the discoveries made in 2015. Eni, through its subsidiary Eni North Africa BV, is operator of Contract Area D with a 100% working interest in the exploration phase. Eni has been present in Libya since 1959 and currently produces 350,000 barrels of oil equivalent per day in equity in the country.

4 Apr 2017

CHC Announces New Contract with Faroe Petroleum

CHC Group (the "Company" or "CHC") today announced it has been awarded a new contract with Faroe Petroleum to provide helicopter services in support of their exploration drilling program at the Brasse Field in the North Sea."We are excited to work with Faroe Petroleum as their aviation partner in this project," said Arne Roland, CHC Regional Director for Nordic Countries, Eastern .... [+ read more] Europe, Caspian and Canada (NECC). "This project allows us to continue to build on our decades of experience supporting oil and gas customers in the Norwegian Continental Shelf as we continue to evolve our services and technology to best meet their needs."The operation will begin in summer 2017, flying from CHC's base in Bergen using a Sikorsky S-92, which has a proven safety and availability record, reaching more than one million fleet hours of service in 2016.Faroe Petroleum’s drilling program is expected to last for an initial period of approximately 70 days and the contract includes an option to extend CHC’s services beyond this initial period."CHC is proud to continue a safe and reliable transportation offering to customers in and around the North Sea," said Karl Fessenden, President and CEO of CHC Helicopter. "We look forward to helping Faroe Petroleum meet their transportation needs throughout this project and are eager to start flying on their behalf upon project commencement later this year."

28 Mar 2017

Drilling permit for well 7220/11-4 in production licence 609

The Norwegian Petroleum Directorate has granted Lundin Norway AS a drilling permit for well 7220/11-4, cf. Section 8 of the Resource Management Regulations. Well 7220/11-4 will be drilled from the Leiv Eiriksson drilling facility at position 72°2' 27.56" north and 20°33' 8.1" east. The drilling programme for well 7220/11-4 relates to the drilling of an appraisal well in production licence .... [+ read more] 609. Lundin Norway AS is the operator with an ownership interest of 40 per cent, the other licensees are Idemitsu Petroleum Norge AS with 30 per cent and DEA Norge AS with 30 per cent. The area in this licence consists of the blocks/part of blocks 7220/6, 7220/9, 7220/11, 7220/12 and 7221/4. The well will be drilled about two kilometres south of the discovery well 7220/11-1 in production licence 609. Production licence 609 was awarded in the 21st licensing round in 2011. The permit is contingent upon the operator securing all other permits and consents required by other authorities before commencing drilling activities.

23 Mar 2017

Statoil receives consent for exploration drilling in block 7121

Statoil has received consent to drill exploration well 7121/8-1 in the Barents Sea. Statoil has received consent to drill exploration well 7121/8-1 in production licence 849. The well is to be drilled in a prospect named Blåmann. The drill site is in 376 metres of water, around 113 kilometres north-west of Hammerfest and 25 kilometres from Goliat. The drilling work .... [+ read more] is scheduled to take 25 days. The consent also covers drilling of a possible sidetrack, with the designation 7171/8-1A, which will take 13 days. The well is to be drilled by Songa Enabler, which is a semi-submersible drilling facility of the CAT D type. It was delivered by the Daewoo yard in South Korea in 2016, is registered in Norway and classified by DNV-GL. Songa Offshore received Acknowledgement of Compliance (AoC) for the facility from the PSA in July 2016.

20 Mar 2017

Borr Drilling Intends to Acquire 15 High-Specification Jackup Rigs from Transocean

Borr drilling Limited is pleased to announce the signing of a letter of intent with Transocean for the acquisition of 15 high-specification jack-up rigs. The transaction consists of Transocean's entire jack-up fleet, comprising 10 rigs in Transocean's fleet and 5 new-builds under construction at Keppel Fels Limited. Total consideration for the transaction is expected to be approximately USD 1.35 bn and .... [+ read more] includes remaining contract backlog and remaining yard instalments to Keppel Fels for the five new-builds. The board of directors of Keppel Fels has pre-approved the novation of the new-building contracts. A deposit has in line with what has been agreed between the parties been paid from Borr to Transocean. Borr has secured financing for the transaction through a private placement of equity securities. The transaction is subject to the parties executing definitive agreements and satisfying formal closing conditions, including a final approval from the boards of directors of both companies. The completion of the transaction is expected to take place before the end of may 2017.

16 Mar 2017

Dry well northwest of the 7220/8-1 Johan Castberg discovery in the Barents Sea – 7318/12-2

Eni Norge AS, operator of production licence 716, has completed the drilling of wildcat well 7318/12-2. The well, which was drilled about 80 km northwest of the 7220/8-1 Johan Castberg discovery in the Barents Sea, is dry. The primary exploration target for the well was to prove petroleum in Middle and Lower Jurassic reservoir rocks (Stø and Nordmela formations). .... [+ read more] The secondary exploration target for the well was to prove petroleum in Upper Triassic reservoir rocks (Fruholmen and Snadd formations). Drilling to secondary exploration targets was contingent upon discoveries in the primary exploration target. Well 7318/12-2 encountered about 60 metres of dense sandstone rocks in the Stø og Nordmela formations. Data has been acquired, and samples were taken. This is the first exploration well in production licence 716. The licence was awarded in 2013 in the 22nd licensing round. Well 7318/12-2 was drilled to a vertical depth of 3501 metres below the sea surface and was terminated in the Nordmela formation in the Lower Jurassic. Water depth is 418 metres. The well will be permanently plugged and abandoned. Well 7318/12-2 was drilled by Scarabeo 8, which will now drill a development well on the Goliat field in the Barents Sea, where Eni Norge AS is the operator.

15 Mar 2017

Boné Exploration Well Results

Faroe Petroleum, the independent oil and gas company focusing principally on exploration, appraisal and production opportunities in Norway and the UK, announces that drilling has reached target depth on the7183/12-2 Boné exploration well in the Barents Sea (Faroe 20%). The Boné well has been drilled to a total depth of 3,501 metres. The well encountered approximately 106 metres of gross .... [+ read more] water bearing reservoir in the primary target, the Realgrunnen Group. Data acquisition and sampling has been undertaken including logging and water sampling. The Boné exploration well was operated by Eni using the Scarabeo 8 drilling rig and is now being plugged and abandoned as planned. Licence PL716 was awarded to Faroe in June 2013 in the Norwegian 22nd Licensing Round together with co-venturers Eni Norge AS (30% and operator), Bayerngas Norge AS (20%), Petoro AS (20%) and Point Resources AS (10%).

14 Mar 2017

Wärtsilä to optimise performance and uptime of four Songa Offshore drilling rigs

The technology group Wärtsilä has signed a five-year technical management and services agreement with Songa Offshore for four Cat-D type semi-submersible drilling rigs operating in the North Sea. Through the partnership with Wärtsilä, Songa Offshore ensures optimal performance and maximum availability of the Wärtsilä engines and thrusters on board the drilling rigs, which operate in extremely harsh conditions. This is possible .... [+ read more] with real-time knowledge of the actual condition of the equipment, provided by Wärtsilä’s digital offering. Under the agreement, signed in December 2016, Wärtsilä offers Songa Offshore dynamic maintenance planning and inspections, real-time condition monitoring of engines and thrusters as well as equipment analysis reports. Improved maintenance scheduling leads to better predictability and improved cost efficiency. The agreement concerns four of the customer’s rigs: Songa Equinox, Songa Encourage, Songa Endurance and Songa Enabler. Each rig is equipped with six Wärtsilä 32 engines. Two of the rigs have six Wärtsilä FS3500 steerable thrusters, and two have six Wärtsilä FS3510 steerable thrusters. The rig type is designed for efficient year-round drilling, completion, testing and intervention operations in harsh conditions. “We are very excited about this first long-term service agreement with Songa Offshore. With our expertise, we ensure that Songa Offshore’s rigs can reach their full performance in the harsh environment of the North Atlantic basin,” says Cato Esperø, Sales Director, Wärtsilä Norway.

13 Mar 2017

Seadrill Limited Announces Settlement of West Mira Arbitration

Seadrill Limited ("Seadrill" or "the Company") announces today that it has reached a settlement agreement with Hyundai Samho Heavy Industries Co Ltd. ("HSHI") in relation to the West Mira ("the Unit") arbitration. Seadrill will receive a cash payment of $170 million in March 2017 as full settlement of the dispute. Arbitration proceedings began in October 2015 following the cancellation of .... [+ read more] the construction contract for the West Mira and were expected to conclude during the first half of 2018. This settlement agreement brings an early conclusion to the arbitration process. The Company will take a non-cash impairment of approximately $44 million to reflect the difference between the carrying value of the West Mira receivable and the cash payment to be received. As part of this settlement, Seatankers, a related party, has purchased the West Mira from HSHI. Seatankers is an asset holding company and is not expected to engage in offshore drilling activities in competition with Seadrill. The Company expects to execute an agreement with Seatankers for the commercial and technical management of the West Mira as well as a right of first refusal for purchase of the Unit.

10 Mar 2017

Minor gas discovery east of the Alve field in the Norwegian Sea – 6507/3-12 and 6507/3-12 A

Statoil Petroleum AS, operator of production licence 159 B, has completed the drilling of wildcat well 6507/3-12 and appraisal well 6507/3-12 A. The wells proved gas. The wells were drilled about six kilometres east of the Alve field in the northern part of the Norwegian Sea and about 200 kilometres west of Sandnessjøen. The primary exploration target for wildcat well .... [+ read more] 6507/3-12 was to prove petroleum in Middle Jurassic reservoir rocks (Garn and Not formations). The secondary exploration target was to prove petroleum in Middle Jurassic reservoir rocks (Ile formation). Another goal was to collect geological data if Cretaceous sandstone rocks were present. The primary target for appraisal well 6507/3-12 A was to delineate the Cretaceous gas discovery (Lysing formation). Well 6507/3-12 encountered a total gas column of about 7 metres in a Late Cretaceous sandstone layer with good reservoir properties. In the primary and secondary exploration targets, the well encountered about 30-metres of aquiferous sandstone in the Garn and Not formations, and about 65 metres of aquiferous sandstone in the Ile and Tofte formations, all with good to moderate reservoir properties. Well 6507/3-12 A was stopped due to technical issues regarding presumed gas-filled sandstone, and no further attempts were made to drill the appraisal well. Preliminary estimations place the size of the discovery between one and five billion standard cubic metres (Sm3) of recoverable gas. The licensees will assess the discovery along with other nearby discoveries/prospects with regard to a possible development. Well 6507/3-12 was not formation-tested, but data has been collected and samples were taken. These are the third and fourth exploration wells in production licence 159 B. The licence was carved out of production licence 159 on 13 August 2004. Well 6507/3-12 was drilled to a vertical depth of 3428 metres below the sea surface, and was terminated in the Tofte formation in the Early Jurassic. Well 6507/3-12 A was drilled to a vertical depth of 2529 metres below the sea surface and was terminated in the Springar or Nise formation in the Late Cretaceous. Water depth is 381 metres. The wells will be permanently plugged and abandoned. Wells 6507/3-12 and 6507/3-12 A were drilled by the Deep Sea Bergen drilling facility, which will now proceed to the Åsgard field in the Norwegian Sea to complete production well 6506/12-S-4 BH.

7 Mar 2017

Consent to use Songa Enabler at Snøhvit

Statoil has received consent to use Songa Enabler for drilling a production well at Snøhvit. Snøhvit is a gas field in the Barents Sea north-west of Hammerfest. Statoil is the field's operator. Snøhvit has been developed using a subsea production facility. The gas is transported onshore through a 143-kilometre-long pipeline to Melkøya, off Hammerfest. Production at Snøhvit began in 2007. .... [+ read more] On 15 July 2016, Statoil received consent to use the Songa Enabler mobile drilling facility to drill three wells on the field. We have now given Statoil consent to drill a fourth well using the same facility. The well is to be drilled in the same well template as two of the first wells. The well template is in 318 metres of water. Drilling is scheduled to begin in mid-march 2017 and will last 65 days. Songa Enabler is a semi-submersible drilling facility of the CAT D type. It was delivered by the Daewoo yard in South Korea in 2016, is registered in Norway and classified by DNV-GL. Songa Enabler was issued with an Acknowledgement of Compliance (AoC) by the PSA in July 2016.

2 Mar 2017

Repsol receives consent for exploration drilling

Repsol has received consent to drill exploration well 6705/7-1 in the Norwegian Sea. Repsol Norge AS (Repsol) is the operator for production licence 705 in the Norwegian Sea. The PSA has given Repsol consent to drill exploration well 6705/7-1 in a prospect named Stordal. The drilling site is in the deep-water section of the Norwegian Sea, around 395 kilometres west .... [+ read more] of Bodø. Water depth at the site is 1410 metres. Drilling is scheduled to start in early March and to last 33 days, or 48 days if a discovery is made. The well is to be drilled by Transocean Spitsbergen, which is a semi-submersible drilling facility of the Aker H-6e type, owned and operated by Transocean Offshore Ltd. It was built at the Aker Stord yard in 2009, is registered in the Marshall Islands and classified by DNV GL. Transocean Spitsbergen received a new Acknowledgement of Compliance from the PSA in November 2012 following a change of ownership.

2 Mar 2017

Aker BP receives consent to drill an exploration well at Volund

Aker BP has received consent to drill exploration well 24/9-11S on the Volund field. The well is to be drilled by Transocean Arctic. Aker BP ASA (Aker BP) is the operator of the Volund field, in the North Sea, around 220 kilometres west of Tananger in Rogaland county. Volund is an oil field that has been developed using a subsea facility .... [+ read more] tied back to the Alvheim FPSO unit. The PSA has given Aker BP consent to drill an exploration well with the designation 24/9-11S on the field. The consent also covers a potential sidetrack. The object of the drilling is to investigate the potential of a formation 7.5 kilometres west of the subsea facility at Volund. Water depth at the site is 122 metres. The drilling work is scheduled to take 28 days. Any potential sidetrack will be in addition to this. Drilling is to be performed using the Transocean Arctic mobile drilling facility, which is owned and operated by Transocean Ltd. Transocean Arctic was built in 1987 by Mitsubishi Heavy Industries in Japan. The facility was upgraded in 2004 and received Acknowledgement of Compliance (AoC) from the PSA in July of that year. It is registered in the Marshall Islands and classified by DNV GL.

1 Mar 2017

Drilling permit for well 6507/3-12 A in production licence 159 B

The Norwegian Petroleum Directorate has granted Statoil Petroleum AS a drilling permit for well 6507/3-12 A, cf. Section 8 of the Resource Management Regulations. Well 6507/3-12 A will be drilled with the Deepsea Bergen drilling facility at position 65°58' 3.93" north and 7°56' 1.64" east. The drilling program for well 6507/3-12 A relates to the drilling of an appraisal well .... [+ read more] in production licence 159 B. Statoil Petroleum AS is the operator with an ownership interest of 85 per cent. The other licensee is Dong E&P Norge AS with 15 per cent. The area in this licence is part of block 6507/3. The well will be drilled about 11 kilometres southwest of the Norne field. Production licence 159 was awarded in licensing round 12 Part B on the Norwegian shelf, and production licence 159 B was carved out on 13 August 2004. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activity.

24 Feb 2017

Island Innovator has left Hanøytangen

Semco Maritime, Norway has completed the upgrade project on the rig Island Innovator. The rig left the Semco Maritime yard at Hanøytangen on Friday 24 February. It has been in the yard since September 2016. After various modification and service work the rig will now mobilize to the Edvard Grieg field in the Norwegian part of the North Sea to .... [+ read more] work for Lundin Petroleum, drilling for 16/1-27 appraisal well for 30 to 35 days. During the yard stay the 5-year SPS (Special Periodic Survey) classification has been performed on the rig. Besides that an extensive airgap project has been carried out, including blinding of 64 windows and watertight doors. The semi-submersible rig, which was built in 2012, has also undergone contractual specific modification scopes. “It has been a pleasure working together with the Island Drilling organisation and the Oddfjell project team”, says Nikolaj Vejlgaard, Vice President of operations at Semco Martime. He adds, “we are proud to have completed another rig upgrading project for a satisfied client and look forward to continuing the cooperation with Island Drilling and Odfjell”. With the facilities at Hanøytangen Semco Martime offers one of the most versatile yards, which has the deepest dry dock in Europe with a depth of 17 meter and an ultra-deep-water quayside facility with a water depth of more than 90 meter.

23 Feb 2017

Drilling permit for well 6705/7-1 in production licence 705

The Norwegian Petroleum Directorate has granted Repsol Norge AS a drilling permit for well 6705/7-1, cf. Section 8 of the Resource Management Regulations. Well 6705/7-1 will be drilled by the Transocean Spitsbergen drilling facility at position 67°15'5.14" north and 5°10'29.12" east, after completing the drilling of wildcat well 205/23-3a on the British side for Hurricane. The drilling programme for well .... [+ read more] 6705/7-1 relates to the drilling of a wildcat well in production licence 705. Repsol Norge AS is the operator with an ownership interest of 40 per cent. The other licensees are DEA Norge AS with 30 per cent and M Vest Energy AS with 30 per cent. The area in this licence consists of blocks 6705/8 and 6705/9, in addition to parts of blocks 6705/7 and 6705/10. The well will be drilled about 330 kilometres west of Bodø. Production licence 705 was awarded on 21 June 2013 (22nd licensing round). This is the first well to be drilled in the licence area. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing the drilling activities.

17 Feb 2017

Newbuild Jackup Delivered to National Drilling Company

Lamprell (ticker: LAM), a leading provider of diversified engineering and contracting services to the energy industry, announces the completion of construction on a further jackup drilling rig, the “Al Hudairiyat”, and its delivery to Abu Dhabi’s National Drilling Company (“NDC”), within budget and as scheduled. Completion and delivery of the jackup rig was marked at an inauguration ceremony held at Lamprell’s .... [+ read more] Hamriyah facility in the U.A.E. yesterday. The rig was completed to the highest standards of quality using the latest in drilling system technology from our suppliers and will depart the facility in Q1 en route to its drilling location in Abu Dhabi. The contract for the NDC “Al Hudairiyat” rig was signed in November 2014 and this is the eighth rig in a series of nine being built and delivered by Lamprell to NDC. All nine rigs have been designed according to the Cameron LeTourneau Super 116E (Enhanced) Class design. The remaining rig is proceeding on schedule and will be delivered as planned in 1H 2017.

13 Feb 2017

New Build Delivery

On Feb 13th, “Bluewhale 1”, the most advanced ultra-deep-water semisubmersible drilling rig, built by Yantai CIMC Raffles Offshore Limted (referred to as “CIMC Raffles”), was named and delivered in Yantai. As the first turnkey project in Chinese offshore ultra deepwater field, “Bluewhale 1” will be operated by CPOE together with Bluewhale to carry out the offshore energy exploration. .... [+ read more]

13 Feb 2017

Rig Delivered

“Blue Whale One”, a semi-submersible drilling platform manufactured by Yantai CIMC Raffles Offshore Limited (CIMC Raffles), was named and delivered to the project owner at Yantai on February 13, 2017. Equipped with two drilling towers, the platform is the most advanced semi-submersible drilling platform on earth, breaking the world’s records for the operating depth and drilling depth. In the meantime, .... [+ read more] it is the first “turn-key project” completed by a Chinese shipbuilder in the ultra-deep water field, making it a milestone in the nation’s offshore engineering sector. The platform will be jointly operated by Blue Whale and CNPC Offshore Engineering Company Limited (CPOE) for ocean energy exploration according to a previously signed service agreement between the two sides.

13 Feb 2017

Oil discovery in the Filicudi prospect in the southern Barents Sea

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that its wholly owned subsidiary Lundin Norway AS (Lundin Norway) has made an oil and gas discovery in the main well 7219/12-1 and is presently drilling a sidetrack 7219/12-1A on the Filicudi prospect. The wells are located in PL533 approximately 40 km southwest of Johan Castberg and 30 km northwest of the .... [+ read more] Alta and Gohta discoveries on the Loppa High in the southern Barents Sea. The main objective of the well was to prove oil in Jurassic and Triassic sandstone reservoirs. The well encountered a gross 129 metres hydrocarbon column of high quality sandstone reservoir characteristics, with 63 metres of oil and 66 metres gas in the Jurassic and Triassic targets. Extensive data acquisition and sampling has been carried out including coring, logging and oil and gas sampled from the wireline tools. The sidetrack well has reached total depth and has confirmed the reservoir and hydrocarbon column. The gross resource estimate for the Filicudi discovery is between 35 and 100 million barrels of oil equivalents (MMboe). Well results indicate significant upside potential that require further appraisal drilling. Filicudi is on trend with the Johan Castberg discovery, with resources of approximately 500 MMboe, in similar reservoir intervals. Multiple additional prospects have been identified on the Filicudi trend within PL533 with total gross unrisked prospective resource potential for the trend of up to 700 MMboe. The partnership is considering the drilling of up to two additional prospects in 2017. There are two independent high graded prospects within PL533, Hufsa containing gross unrisked prospective resources of 285 MMboe and Hurri with gross unrisked prospective resources of 218 MMboe. The success at Filicudi has reduced the risk and both prospects carry a 25 percent chance of success. The semisubmersible drilling rig Leiv Eiriksson will after completion of the well on the Filicudi prospect in PL533 move to the Gohta discovery in PL492 to drill a second delineation well on this discovery. Lundin Norway is the operator of both PL533 and PL492 and holds a 35 percent and 40 percent working interest in these respective licences.

10 Feb 2017

Ocean Rig Athena On Route to Greece

Ocean rig has reached an agreement with ConocoPhillips to terminate the contract on the Ocean Rig Athena. ConocoPhillips will pay a termination fee as part of the termination agreement. The Ocean Rig Athena has now left Las Palmas and is on route to Greece where the rig will be cold stacked. .... [+ read more]

8 Feb 2017

Drilling permit for well 16/1-27 in production licence 338

The Norwegian Petroleum Directorate has granted Lundin Norway AS a drilling permit for well 16/1-27, cf. Section 8 of the Resource Management Regulations. Well 16/1-27 will be drilled from the Island Innovator drilling facility, at position 58°50’18.11” north and 2°11’56.83” east, in a southwesterly extension of the Edvard Grieg field in the central part of the North Sea. The drilling .... [+ read more] programme for well 16/1-17 relates to the drilling of an appraisal well on Edvard Grieg in production licence 338. Lundin Norway AS is the operator with an ownership interest of 65 per cent. The other licensees are OMV (Norge) AS with 20 per cent, and Wintershall Norge AS with 15 per cent. The area in this licence consists of part of block 16/1. The well will be drilled about 3 kilometres west of the Edvard Grieg platform. Production licence 338 was awarded on 17 December 2004 (APA 2004). This is the 11th exploration well to be drilled in the licence area and the 8th exploration well on the Edvard Grieg field. The permit is contingent upon all other permits and consents required by other authorities being granted before drilling activities commence.

3 Feb 2017

Gas discovery on the Valemon field in the North Sea – 34/11-6 S

Statoil Petroleum AS, operator of production licence 193 D, has concluded the drilling of wildcat well 34/11-6 S. The well was drilled from the Valemon facility, 160 km northwest of Bergen. The objective of the well was to prove petroleum in the Middle Jurassic (the Brent group). The well encountered two gas columns of about 80 and 35 metres in .... [+ read more] the Tarbert and Ness formations, respectively. There were 50 metres of sandstone with moderate to good reservoir quality in the Tarbert formation and 10 metres of sandstone with poor reservoir quality in the Ness formation. Preliminary estimates place the size of the discovery between 3 - 8 million standard cubic metres (Sm3) of recoverable oil equivalents. The well will be completed and will start production from the Valemon facility. Data acquisition was carried out. This is the first exploration well in production licence 193 D. Well 34/11-6 S was drilled to a vertical depth of 4337 metres below the sea surface, and was terminated in the Drake formation in the Lower to Middle Jurassic. Water depth at the site is 133 metres. Well 34/11-6 S was drilled by the West Elara drilling facility, which is permanently stationed at the Valemon facility.

31 Jan 2017

Eni successfully appraises Merakes discovery offshore Kalimantan, Indonesia

Eni successfully drilled and tested Merakes 2, the first appraisal well of the Merakes discovery under the Production Sharing Contract (PSC) in East Sepinggan. The block is located in the prolific offshore Kutei Basin and the Merakes discovery is 35km from the Eni-operated Jangkrik field, which is expected to start producing through a Floating-Production Unit in the second quarter of this .... [+ read more] year. The well, drilled to a depth of 2,732m in 1,269m of water depth, encountered 17 meters of clean sands with very good petrophysical characteristics of Pliocene age confirming the the extension also in this new area of the 2014 discovery by the well Merakes 1. The production test, which was limited by surface facilities, recorded an excellent gas deliverability of the Merakes reservoir, and allowed to collect all the necessary data and information to perform all the studies for the future commercial exploitation of the discovery. Merakes discovery is currently estimated to have 2.0 Tcf of gas in place with further additional potential to be evaluated. The proximity of Merakes 2 discovery to the Jangkrik field will allow to maximizing the synergies with existing nearby infrastructures as well as to reduce costs and time of the execution of the future subsea development it confirms the success of Eni the “near field” exploration and appraisal strategy . Eni is the operator of East Sepinggan PSC with its affiliate Eni East Sepinggan Limited holding 85% Participating Interest while Pertamina Hulu Energy holds the remaining 15%. Eni has been operating in Indonesia since 2001and currently has a large portfolio of assets in exploration, production and development. In the Kutei Basin in early 2014, Eni started the development activities of the deep offshore Jangkrik gas field in the Muara Bakau PSC. Production activities are located in the Mahakam River delta, East Kalimantan through the participated Company VICO Ltd (Eni 50%, Saka 50%) operator of the Sanga Sanga PSC that provides an average equity production of 16,000 barrels of oil equivalent per day.

30 Jan 2017

Lundin receives consent for exploration drilling on the Edvard Grieg field

Lundin has received consent to carry out exploration drilling of well 16/1-27 on the Edvard Grieg field. Lundin is the operator of the Edvard Grieg field, in the North Sea, around 140 kilometres west-southwest of Stavanger. The field is one of the largest oil fields on the Norwegian Continental Shelf. Production from the field began in 2015. The well to .... [+ read more] be drilled is an appraisal well in a structure named Edvard Grieg SW. Water depth at the site is 138 metres. Drilling is scheduled to begin on 1 March 2017 and will last 44 days. The well is to be drilled by the Island Innovator mobile drilling facility. The facility is a type GM4000, delivered by the COSCO Shipyard in China in 2012. It is owned by Island Drilling Company and operated by Odfjell Drilling. Island Innovator was issued with an Acknowledgement of Compliance (AoC) by the PSA in August 2013.

27 Jan 2017

Statoil receives consent to use Songa Encourage for well activities

Statoil has received consent to use Songa Encourage for well activities at Norne, Norne satellites and Alve. Statoil is the operator of the Norne field in the Norwegian Sea, west of Mo i Rana in Nordland county. The field has been developed using a floating production and storage unit, tied to the well templates on the seabed. Water depth at the .... [+ read more] Norne field is 380 metres. The oil is transported from the Norne facility by tanker, while the gas is piped to Kårstø in Rogaland county and on to Germany. Production at Norne began in 1997. The Alve field, which is 16 kilometres southwest of Norne, and other satellite fields are tied back to the Norne facility. Statoil has received consent to use the Songa Encourage mobile drilling facility to perform well activities on these fields. The activities include drilling wells for production or injection, well overhaul and other intervention work, as well as plugging. Songa Encourage is a semi-submersible drilling facility of the Cat D type, owned and operated by Songa Offshore. It was built by the Daewoo yard in South Korea in 2016, is registered in Norway and classified by DNV GL. Songa Encourage was issued with an Acknowledgement of Compliance (AoC) by the PSA in April 2016.

24 Jan 2017

Borr Drilling Limited completes the delivery of jack-up rigs from Hercules Offshore

Borr Drilling Limited announced today that it has completed the delivery of the Frigg (formerly Hercules Resilience) and the Ran (formerly Hercules Triumph) from Hercules Offshore. The two rigs are KFELS Super A class design, built at Keppel, Singapore, in 2013. .... [+ read more]

24 Jan 2017

Borr Drilling Limited completes the delivery of jack-up rigs from Hercules Offshore

Borr Drilling Limited announced today that it has completed the delivery of the Frigg (formerly Hercules Resilience) and the Ran (formerly Hercules Triumph) from Hercules Offshore. The two rigs are KFELS Super A class design, built at Keppel, Singapore, in 2013. .... [+ read more]

24 Jan 2017

Newbuild Delay

Ensco recently entered into an amendment to the ENSCO DS-10 drillship construction contract (the “Amendment”) with Samsung Heavy Industries (“SHI”), the shipyard constructing the ENSCO DS-10 (“Drillship”). Under the terms of the Amendment: The delivery date for the Drillship has been extended to March 31, 2019 (the “Extended Delivery Date”). Ensco may elect to take delivery of the Drillship earlier upon .... [+ read more] giving SHI 75 days’ advance notice. Notwithstanding the Extended Delivery Date, SHI agreed to complete construction of the Drillship by March 31, 2017. Payment of $75 million of the approximately $309 million unpaid balance of the purchase price for the Drillship has been deferred to March 31, 2019, or such earlier date as Ensco may elect to take delivery of the Drillship. The remaining $234 million of the purchase price is to be paid in January 2017.

24 Jan 2017

Oil and gas discovery northwest of 7220/11-1 (Alta) in the Barents Sea - 7219/12-1 and 7219/12-1 A

Lundin Norway AS, operator of production licence 533, has completed the drilling of wildcat well 7219/12-1 and appraisal well 7219/12-1 A. The well proved oil and gas. The wells were drilled about 32 kilometres northwest of discovery well 7220/11-1 (Alta) and about 37 kilometres southwest of discovery well 7220/8-1 Johan Castberg. The primary and secondary exploration targets for wildcat well .... [+ read more] 7219/12-1 were to prove petroleum in two Early Jurassic and Late/Middle Triassic reservoir levels (Tubåen and Fruholmen formations). The primary exploration target for appraisal well 7219/12-1 A was to collect geological data in Early Jurassic/Late Triassic sandstone rocks (Nordmela and Tubåen formations). Well 7219/12-1 proved a total oil column of about 60 metres and an overlying total gas column of about 60 metres, of which 55 metres and 45 metres, respectively, were in sandstone with good reservoir properties in the Tubåen formation. Well 7219/12-1 A confirmed a mostly equivalent gas and oil column in the Nordmela and Tubåen formations with good reservoir properties. Preliminary estimations of the size of the discovery are between 5.5 and 16 million standard cubic metres (Sm3) of recoverable oil equivalents. Further delineation and production testing of the discovery will be assessed. The wells were not production tested, but extensive data acquisition and sampling have been carried out. These are the second and third exploration wells in production licence 533. The licence was awarded in the 20th licensing round in 2009. Well 7219/12-1 was drilled to a vertical depth of 2475 metres below the sea surface and was terminated in the Snadd formation in Late Triassic. Well 7219/12-1 A was drilled to a vertical depth of 1800 metres below the sea surface and terminated in the Fruholmen formation in Late Triassic. Water depth is 323 metres. The wells will now be temporarily plugged and abandoned. Wells 7219/12-1 and 7219/12-1 A were drilled by the Leiv Eiriksson drilling facility, which will now proceed to production licence 492 in the Barents Sea to drill appraisal well 7120/1-5 where Lundin Norway AS is the operator.

23 Jan 2017

Licence Update Frontier Exploration Licence 2/14 Southern Porcupine Basin

Providence Resources P.l.c. (PVR LN, PRP ID), the Irish based Oil and Gas Exploration Company, provides an update on the Frontier Exploration Licence (”FEL”) 2/14, which lies in c. 2,250 metre water depth in the southern Porcupine Basin and is located c. 220 kilometres off the south west coast of Ireland. The licence is operated by Providence Resources P.l.c. (“Providence”, 80%) .... [+ read more] on behalf of its partner Sosina Exploration Limited (“Sosina”, 20%), who are collectively referred to the “JV Partners”. FEL 2/14 contains the Paleocene “Druid” and the Lower Cretaceous “Drombeg” exploration prospects. The Minister of State for the Department of Communications, Climate Action and Environment has given his consent to the progression to the second phase of the licence, subject to the completion of the agreed work programme which includes the drilling of the 53/6-A exploration well on the Paleocene Druid prospect and the subsequent integration of the well data into a comprehensive assessment of the petroleum potential of the licence. In November 2016, the Company signed a drilling contract for the provision of the Stena IceMAX drill-ship to drill an exploration well in FEL 2/14 during 2017. The drilling contract provides for one firm well, plus an additional option, which is electable at the discretion of the JV Partners for the drilling of a second follow -on well. Other key service contracts are now being finalized for the drilling operations for the planned 53/6-A exploration well. Based on the latest project timeline and, subject to standard regulatory approvals and consents, the 53/6-A exploration well is currently planned to spud in June 2017.

19 Jan 2017

Drilling permit for wellbore 7219/12-1 A in production licence 533

The Norwegian Petroleum Directorate has granted Lundin Norway AS a drilling permit for wellbore 7219/12-1 A, cf. Section 8 of the Resource Management Regulations. Wellbore 7219/12-1 A will be drilled from the Leiv Eiriksson drilling facility at position 72°12' 44.2" north and 19°46' 38.3" east. The drilling programme for wellbore 7219/12-1 A relates to the drilling of an appraisal well .... [+ read more] in production licence 533. Lundin Norway AS is the operator with an ownership interest of 35 per cent. The other licensees are Aker BP ASA with 35 per cent and DEA Norge AS with 30 per cent. The area in this licence consists of the blocks 7219/12 and 7220/10. The well will be drilled about 24 kilometres north of the discovery well 7220/10-1 in production licence 533. Production licence 533 was awarded on 15 May 2009 in the 20th licensing round. The permit is contingent on the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

18 Jan 2017

Drilling permit for wellbore 6507/3-12 in production licence 159 B

The Norwegian Petroleum Directorate has granted Statoil Petroleum AS a drilling permit for wellbore 6507/3-12, cf. Section 8 of the Resource Management Regulations. Wellbore 6507/3-12 will be drilled from the Deepsea Bergen drilling facility at position 65° 58' 3.93" north and 7° 56' 1.64" east. The drilling program for wellbore 6507/3-12 relates to the drilling of a wildcat well in .... [+ read more] production licence 159 B. Statoil Petroleum AS is the operator with an ownership interest of 85 per cent. The other licensee is Dong E&P Norge AS with 15 per cent. The area in this licence consists of a part of block 6507/3. The well will be drilled about 11 kilometres southwest of the Norne field. Production licence 159 was awarded in licensing round 12 Part B on the Norwegian shelf and production licence 159 B was carved out on 13 August 2004. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

18 Jan 2017

Statoil awarding service contracts for two Cat J rigs

Baker Hughes and Schlumberger will be awarded the contracts for integrated drilling and well services on the Cat J rigs Askepott and Askeladden. The rigs will perform work at Oseberg and the Gullfaks. Initially awarded for four years the contracts include options for two 2-year extensions. The contracts include the following: cementing and pumping, completion, drilling and completion fluids, intergrated drilling .... [+ read more] services. Schlumberger is currently delivering integrated drilling and well services at Mariner and Baker Hughes at Johan Sverdrup. They are both important suppliers for Statoil across the drilling and well disciplines. The Norwegian head offices of both companies are located in Stavanger. “Statoil aims to run safe operations, cut well costs and ensure efficient well deliveries. We look forward to working closely with these two suppliers on the licences’ own rigs. These contracts will help increase activities on the Norwegian continental shelf, ensure predictability, and create more jobs,” says Geir Tungesvik, Statoil’s senior vice president for drilling & well. Oseberg Cat J will contribute to continued development of the Oseberg area. From the autumn of 2017 the rig will drill wells for the Vestflanken 2 project. Later the rig may be used for further developing the area in the Oseberg Future Development, phases 2 and 3. The past four years the Gullfaks field has seen substantial investments and upgrading. In 2016 consent to extended field life to 2034 was granted, almost 30 years beyond the original PDO estimate, which was 2005. The Cat J rig will be essential to the continued development of the Gullfaks field. Owned by the Gullfaks and Oseberg licences the Cat J jack-up rigs are tailored to the conditions in the North Sea, where they are scheduled to be installed in the summer and autumn of 2017, respectively. The Cat J rigs are specially designed to perform efficient drilling operations on subsea development solutions in addition to conventional surface drilling from fixed platforms. The rigs have derrick, allowing 40-metre pipe joints to be put together to increase the efficiency of the operations. They feature automatic pipe handling and the opportunity to perform parallel operations – i.e. making up pipe while drilling. They will be instrumental in ensuring that the licences recover all profitable reserves, and may also be used for exploration. The introductory Askeladden drilling programme focuses on proven reserves and gas blowdown wells on one of the Gullfaks satellite fields. Askepott will primarily drill through the unmanned wellhead platform at Vestflanken 2, which is part of Oseberg.

18 Jan 2017

Songa Encourage update

Following the 2 January 2017 water ingress into a pump room, Songa Encourage is currently close to Kristiansund, Norway, for equipment overhaul and repair which are progressing on schedule. The rig is expected to be back in operations early February 2017. .... [+ read more]

16 Jan 2017

Phoenix South-2 Well Update

Carnarvon Petroleum Limited (“Carnarvon”) (ASX:CVN) is pleased to inform shareholders that operations at the Phoenix South-2 well have been safely completed and the rig has now left the drilling location. The well drilled an estimated 39 metre hydrocarbon-bearing zone between approximately 5,176 and 5,215 metres with significant gas influx and elevated reservoir pore pressures. The well was unable to assess as .... [+ read more] much as 185 metres of additional potential hydrocarbon bearing Caley reservoir beneath 5,215 metres due to the higher than anticipated pressures being encountered. The higher formation pressures encountered typically support both larger volumes and higher gas and condensate flows rates over a given reservoir. An update on volume estimates will be provided once Carnarvon has had an opportunity to assess all of the information obtained from the well. These results are expected to have a positive impact on volumes assessments in the Phoenix South Caley Sandstone. The joint venture will also assess the results of this well for the purpose of considering the future operations in this area, including quantifying the resources identified in the Phoenix South Barret and Caley Sandstone formations. Unfortunately, the subsurface conditions in this well did not allow for the well to be suspended in a way that would allow for re-entry at a later date.

16 Jan 2017

Halifax 205/23-A - Well Spud

Hurricane Energy plc, the UK based oil and gas company focused on hydrocarbon resources in naturally fractured basement reservoirs, announces the spudding of well 205/23-A (the "Halifax Well") on 15 January 2017. The recently drilled Lancaster Pilot well (205/21a-7) encountered a minimum oil down to (ODT) of 1,620m TVDSS, indicating that the Lancaster oil accumulation is likely to extend .... [+ read more] beyond the Lancaster licence boundary. The recently awarded P2308 licence ("Halifax") is contiguous to, and extends north east from, Hurricane's existing Lancaster licence. The Company believes that if mobile oil can be demonstrated outside of local structural closure by the Halifax Well, then the Lancaster field could extend further north east along the Rona Ridge. A previous well (205/23-2) drilled on the Halifax structure encountered oil and gas shows in sandstones immediately above the basement. In addition, Hurricane's analysis of basement cuttings from the 205/23-2 well indicates the presence of oil thus mitigating the oil charge risk to Halifax. Seismic interpretation indicates the presence of a well-defined fault network within the fractured basement of the Halifax Prospect, analogous to that seen in Lancaster. The Company plans to drill the Halifax Well below local structural closure and will then perform an open hole drill stem test ("DST"). In the event of a successful DST, it is envisaged that the well will be deepened to investigate the oil water contact.

12 Jan 2017

Boné (Dazzler) exploration well commences and Brasse appraisal well added to 2017 drilling programme

Faroe Petroleum, the independent oil and gas company focusing principally on exploration, appraisal and production opportunities in Norway and the UK, is pleased to announce the commencement of the Boné exploration well 7318/12-1 (Faroe 20%) and the decision to drill an appraisal well on the Brasse discovery in the 2017 drilling programme. Licence PL716, which contains the Boné prospect (previously named .... [+ read more] Dazzler), is located in the western part of the Norwegian Barents Sea in a similar structural setting to the Johan Castberg discovery. The primary targets for the well are the Jurassic Stø- and Nordmela sandstones with a secondary target within the Triassic Fruholmen and Snadd sandstone formations. Licence PL716 was awarded to Faroe in June 2013 in the Norwegian 22nd Licensing Round together with co-venturers Eni Norge AS (30% and operator), Bayerngas Norge AS (20%), Petoro AS (20%) and Point Resources AS (10%). The Boné well is being drilled using the Scarabeo 8 drilling rig and the results will be announced when drilling operations are complete. Faroe Petroleum is also pleased to announce that the Licence PL740 partnership has committed to the drilling of an appraisal well on the Brasse discovery in mid-2017 (Faroe 50%). Faroe as operator has entered into a contract with Odfjell Drilling for the use of the semi-submersible drilling rig, Deepsea Bergen, for the drilling operations. Faroe announced the Brasse oil and gas discovery in PL740 in July 2016. The main wellbore 31/7-1 encountered an 18 metre gross gas column and a 21 metre gross oil column, and the sidetrack well (31/7-1A) encountered a 6 metre gross gas column and 25 metre gross oil column, with both wells encountering good quality Jurassic reservoir. Total gross volumes of recoverable hydrocarbons have been estimated by the Company to be 28-54 mmbbls of oil and 89-158 bcf of gas (43-80 mmboe gross in aggregate). The main objectives of the appraisal well are to reduce the uncertainty in the reserves estimates and to provide important additional information for the development project. The Brasse discovery is located within tie-back distance to existing infrastructure: 13 kilometres to the south of the Brage field platform, in which the Company holds a 14.3% working interest and 13 kilometres to the south east of the Oseberg Field Centre.

12 Jan 2017

ExxonMobil Announces New Oil Discoveries Offshore Guyana

ExxonMobil announced today positive results from its Payara-1 well offshore Guyana. Payara is ExxonMobil’s second oil discovery on the Stabroek Block and was drilled in a new reservoir. The Payara-1 well targeted similar aged reservoirs that were proven successful at the company’s Liza discovery. “This important discovery further establishes the area as a significant exploration province,” said Steve Greenlee, president .... [+ read more] of ExxonMobil Exploration Company. “We look forward to working with the government and our co-venturers to continue evaluating broader exploration potential on the block and the greater Liza area.” The well was drilled by ExxonMobil affiliate Esso Exploration and Production Guyana Limited, and encountered more than 95 feet (29 meters) of high-quality, oil-bearing sandstone reservoirs. It was safely drilled to 18,080 feet (5,512 meters) in 6,660 feet (2,030 meters) of water. The Payara field discovery is about 10 miles (16 km) northwest of the 2015 Liza discovery. In addition to the Payara discovery, appraisal drilling at Liza-3 has identified an additional high quality, deeper reservoir directly below the Liza field, which is estimated to contain between 100-150 million oil equivalent barrels. This additional resource is currently being evaluated for development in conjunction with the world-class Liza discovery. “These latest exploration successes are examples of ExxonMobil’s technological capabilities in ultra-deepwater environments, which will enable effective development of the resource for the benefit of the people of Guyana and our shareholders,” Greenlee said. Drilling on Payara began on Nov. 12 with initial total depth reached on Dec. 2. Two sidetracks have been drilled to rapidly evaluate the discovery, and a well test is underway to further evaluate the successful well results. The well data will be analyzed in the coming months to better determine the full resource potential. The Stabroek Block is 6.6 million acres (26,800 square kilometers). Esso Exploration and Production Guyana Limited is operator and holds 45 percent interest in the Stabroek Block. Hess Guyana Exploration Ltd. holds 30 percent interest and CNOOC Nexen Petroleum Guyana Limited holds 25 percent interest.

9 Jan 2017

North Atlantic Drilling Ltd. announces amendment to agreement with Jurong Shipyard

North Atlantic Drilling Ltd. ("NADL" or "the Company") refers to the press release on December 3, 2015, June 7, 2016, August 25, 2016, and October 4, 2016 which announced a standstill agreement and subsequent amendments to defer delivery of the semi-submersible West Rigel ("the Unit"). Today the Company announces an amendment has been agreed with Jurong Shipyard .... [+ read more] Pte Ltd ("Jurong"), which extends the delivery deferral period to July 6, 2017. The extension allows the parties to continue to explore commercial opportunities for the Unit. As previously agreed, in the event no employment is secured for the Unit and no alternative transaction is completed, the Company and Jurong will form a Joint Asset Holding Company for joint ownership of the Unit, to be owned 23% by the Company and 77% by Jurong.

6 Jan 2017

Maersk Drilling takes delivery of newbuild Maersk Invincible

Maersk Drilling has taken delivery of its fourth XLE jack-up rig, the Maersk Invincible, from Daewoo Shipbuilding and Marine Engineering (DSME) in South Korea. Maersk Invincible will now mobilise to the North Sea and will in the second quarter of 2017 commence a five year firm contract with Aker BP for plug and abandonment work on the Valhall field. Maersk .... [+ read more] Invincible is the fourth and final rig in a series of four ultra-harsh environment jack-up rigs to enter Maersk Drilling’s fleet. The first three jack-up rigs have been delivered from the Keppel FELS shipyard.

6 Jan 2017

Hyperdynamics to Engage a More Advanced Drillship from Pacific Drilling for its Upcoming Guinea Exploration Drilling Campaign

Hyperdynamics Corporation (OTCQX: HDYN) today announced that it has accepted a proposal from its drilling contractor, Pacific Drilling, to deploy the Pacific Scirocco drillship in place of the Pacific Bora for Hyperdynamics' upcoming deepwater exploration well offshore the Republic of Guinea. Financial terms under the earlier contract with Pacific Drilling for the Pacific Bora are unchanged. Hyperdynamics plans to spud .... [+ read more] the Fatala-1 well in April 2017. "We are very pleased to be able to engage the Pacific Scirocco for our drilling campaign," said Hyperdynamics President and Chief Executive Officer Ray Leonard. "The Pacific Scirocco is equipped to drill in deeper water -- up to 12,000 feet -- and could handle either of the two optional follow-up fan wells that may be drilled if the Fatala-1 well is successful. "We understand that the Scirocco has been working offshore Nigeria for TOTAL for the last five years and has achieved a 98% up-time record, with no lost-time incidents. Having a rig and a crew that has performed so consistently at such a high level of safety and efficiency should greatly enhance our program," Leonard said. "The Scirocco completes its current contract with TOTAL on January 19 and afterwards will be anchored offshore Abidjan, Ivory Coast. This will enable Schlumberger, our integrated project manager for drilling services, to utilize its base there to outfit the drillship in plenty of time for an April 2017 spud date," he added.

3 Jan 2017

Update on Fatala-1 preperations

Hyperdynamics Corporation (OTCQX: HDYN) announced today that SCS Corporation Ltd. ("SCS"), its wholly owned subsidiary, has signed a Master Service Agreement ("MSA") with Schlumberger to provide essential drilling services for the deepwater exploration well planned for the second calendar quarter of 2017 offshore the Republic of Guinea. "With the signing of this agreement with Schlumberger, we now have the critical .... [+ read more] equipment and most of the drilling services contracts in place to enable us to begin drilling the Fatala-1 deepwater exploration well this spring," said Ray Leonard, Hyperdynamics President and Chief Executive Officer. "Schlumberger is the world's leading provider of oilfield services and equipment to the upstream industry. No one has more experience than Schlumberger in helping oil and gas operators safely and successfully drill for hydrocarbons in some of the deepest waters around the world. "With Schlumberger as integrated project manager for drilling services -- and with Pacific Drilling providing a modern deepwater drillship with an experienced crew -- we have assembled a world-class contingent of equipment, services and highly experienced manpower." Under the MSA, Schlumberger will be the primary provider of services to drill the Fatala-1 well. The estimated value of the MSA for the Fatala-1 well is approximately U.S. $4.5 million. "We are also advancing our discussions with several global oil companies that could farm into a significant portion of our project working interest, provide additional technical expertise and share the project costs and risks," Mr. Leonard added. Hyperdynamics has also achieved other key milestones as it prepares to begin drilling operations.

2 Jan 2017

Water leakage in pump room on Songa Encourage

Just after 12:30 today it was observed water ingress into a pumproom onboard the Songa Encourage. The mobile drilling unit is presently on the Heidrun-field on the Norwegian Continental Shelf. The rig was not in operations, as it was waiting on weather. The water leakage is stopped and the rig is stabilized. There was 79 persons on board the unit and .... [+ read more] no one is injured. The crew mustered according to standard procedure. The company's emergency response team is mobilized, co-ordinates support services and is in continuous contact with Statoil and the relevant authorities. The company has initiated actions to identify the root cause of the incident.

30 Dec 2016

Keppel FELS signs settlement agreement and sale contract

Keppel Corporation Limited (the “Company” or “KCL”) refers to its announcement on 2 August 2013 on the construction contract ("Construction Contract") entered between Keppel FELS Limited (“KFELS”), a wholly-owned subsidiary of Keppel Offshore & Marine Limited (“KOM”), and Parden Holding S.R.L. (“Parden”) for the construction of a KFELS B Class jackup rig (the “Jackup Rig”). Following Parden’s failure to take delivery .... [+ read more] of the Jackup Rig and make payment for the balance 80% of the contract value, among others, KFELS has today, following discussion with the guarantor of Parden’s obligations under the construction contract, entered into a Settlement Agreement with the guarantor. The Settlement Agreement provides for the concurrent execution of a sale contract (“Sale Contract”) with 361 Projects Pte. Ltd. (“Purchaser”), which is an associate of the guarantor, for the purchase of the Jackup Rig at a price equivalent to the balance contract value of the Construction Contract. Under the terms of the Sale Contract, the rig is scheduled for delivery in 4Q 2017. Pursuant to the Sale Contract, a replacement corporate guarantee will be issued by the guarantor to secure the Purchaser’s obligations under the Sale Contract. The above transactions are not expected to have any material impact on the earnings per share or net tangible assets per share of the Company for the year ending 31 December 2016.

29 Dec 2016

Conclusion of Tanzania Drilling

Ophir and its joint venture partners, BG Tanzania (Shell) and Pavilion Energy, have concluded the drilling of two exploration wells offshore Tanzania, safely and on time. The programme comprised Kitatange-1 in Block 1 and Bunju-1 in Block 4. After evaluation, Shell, the operator of Blocks 1 and 4, has confirmed that good quality reservoir was encountered in both wells, however .... [+ read more] hydrocarbons were not found. The Noble Globetrotter 2 rig has been demobilised from site. The two wells fulfil the final exploration commitments as per the exploration licences issued by the Ministry of Energy and Minerals (MEM). Subsequent to the completion of drilling Kitatange-1, a bridging licence has been awarded for the existing discovery Locations in Block 1.

28 Dec 2016

Statoil receives consent for exploration drilling in the Norwegian Sea

The PSA has given Statoil consent to drill exploration well 6507/3-12 in the Norwegian Sea. Statoil is the operator for production licence 159B in block 6507/3 in the Norwegian Sea west of Sandnessjøen. The PSA has given Statoil consent to drill exploration well 6507/3-12 in a prospect named Mim. The drilling location is around 8 kilometres south-west of Norne. Water .... [+ read more] depth at the site is 381 metres. Drilling is scheduled to begin in early January 2017 and will last 27 days. A possible sidetrack from the well will take a further 18 days. The well is to be drilled by Deepsea Bergen, which is a semi-submersible drilling facility owned and operated by Odfjell Drilling. The facility is an Aker H-3 type, built in 1963. It is classified by DNV GL and registered in Norway. Deepsea Bergen was issued with an Acknowledgement of Compliance (AoC) by the PSA in December 2001.

27 Dec 2016

Lundin receives consent for exploration drilling

Lundin Norway AS (Lundin) has received consent to drill exploration well 7120/1-5 in the Barents Sea. Lundin is the operator for production licence 492, comprising blocks 7120/1 and 7120/2 in the Barents Sea. The PSA has given Lundin consent to drill exploration well 7120/1-5 in a prospect named Gohta. The drilling location is around 185 kilometres north-west of Hammerfest. Water .... [+ read more] depth at the site is 368 metres. Drilling is scheduled to begin in late December 2016 and estimated to last 73 days. There will also be a potential well test. The well is to be drilled using the Leiv Eiriksson mobile drilling facility, which is owned and operated by Ocean Rig. The facility is a BINGO 9000 type, built in 2001. It is classified by DNV GL and registered in the Bahamas. Ocean Rig received Acknowledgement of Compliance (AoC) for Leiv Eiriksson from the PSA in July 2008.

23 Dec 2016

Oil discovery east of the Frigg field in the North Sea - 25/2-18 S, 25/2-18 A, 25/2-18 B and 25/2-18 C

Aker BP ASA, operator of production licence 442, has concluded the drilling of wildcat well 25/2-18 S and appraisal wells 25/2-18 A, 25/2-18 B and 25/2-18 C. The wells were drilled four kilometres south of the 25/2-10 S (Frigg Gamma Delta) oil/gas discovery and eight kilometres north of the shut down Frøy field in the North Sea. The objective of .... [+ read more] well 25/2-18 S was to prove petroleum in Middle Jurassic reservoir rocks belonging to the Vestland Group (the Hugin and Sleipner formation). The other three wells were drilled to delineate the discovery. 25/2-18 S encountered two oil columns in the Hugin formation, 30 and 86 metres in total, both of which had about 20 metres of sandstones with moderate to good reservoir quality. Appraisal well 25/2-18 A, which was drilled one kilometre toward the southeast in relation to 25/2-18 S, also encountered two oil columns in the Hugin formation, 34 and 27 metres in total, both with about 25 metres of sandstones with moderate to good reservoir quality. Appraisal well 25/2-18 B, which was drilled 1.4 kilometres north of 25/2-18 S to test the northern segment, encountered the Hugin formation with aquiferous sandstones of about 15 and 75 metres, both with moderate reservoir quality. The well is classified as dry. Appraisal well 25/2-18 C, which was drilled one kilometre west of 25/2-18 S, encountered three oil columns in the Hugin formation totalling 27, 23 and 55 metres, of which 15, 11 and 10 metres of sandstones of moderate to good reservoir quality. A 7-metre condensate column was also encountered, of which 3 metres in sandstones of moderate reservoir quality. Preliminary estimates place the size of the discovery between 4 and 12 million standard cubic metres (Sm3) of recoverable oil equivalents. The licensees are assessing the discovery along with other nearby discoveries with a view towards potential development. Extensive data acquisition and sampling have been carried out. Two successful formation tests (DST) were conducted in 25/2-18 A. The maximum production rate was 600 Sm3 of oil per flow day through a 40/64-inch nozzle opening in the lowermost oil zone. The gas-oil ratio is 140 Sm3/Sm3. The production rate in the uppermost oil zone was 210 Sm3 of oil per flow day through a 24/64-inch nozzle opening. The gas-oil ratio was 164 Sm3/Sm3. The formation tests showed moderate flow properties. The wells are the second, third, fourth and fifth exploration wells in production licence 442. The licence was awarded in APA 2006. Wells 25/2-18 S, 25/2-18 A, 25/2-18 B and 25/2-18 C were drilled to respective measured depths of 3870, 4066, 4335 and 4369 metres below the sea surface, and vertical depths of 3813, 3723, 3803 and 4029 metres below the sea surface. All of the wells were terminated in the Dunlin Group in the Lower Jurassic. Water depth at the site is 121 metres. The wells will be permanently plugged and abandoned. Wells 25/2-18 S, 25/2-18 A, 25/2-18 B and 25/2-18 C were drilled by the Maersk Interceptor drilling facility, which will now proceed to production licence PL 001B - Ivar Aasen, where the plan is for the rig to drill three water injector wells and one oil producer.

22 Dec 2016

Drilling permit for wellbore 7318/12-1 in production licence 716

The Norwegian Petroleum Directorate (NPD) has granted ENI Norge AS a drilling permit for wellbore 7318/12-1, cf. Section 8 of the Resource Management Regulations. Well 7318/12-1 will be drilled from the Scarabeo 8 drilling facility in position 73°7' 46.84" north and 18°43'4.17" east. The drilling programme for wellbore 7318/12-1 concerns the drilling of a wildcat well in production licence 716. .... [+ read more] ENI Norge AS is the operator with an ownership interest of 30 per cent. The other licensees are Bayerngas Norge AS (20 per cent), Faroe Petroleum Norge AS (20 per cent), Petoro AS (20 per cent) and Point Resources AS (10 per cent). The area in this licence consists of blocks 7318/11 and 7318/12. The well will be drilled about 80 kilometres northwest of Johan Castberg and 320 kilometres from the mainland. Production licence 716 was awarded on 21 June 2013 in the 22nd licensing round on the Norwegian shelf. This is the first well to be drilled in the licence. The permit is contingent upon the operator having secured all other permits and consents required by other authorities before the drilling starts.

22 Dec 2016

Delivery of seventh rig to National Drilling Company

Lamprell (ticker: LAM), a leading provider of diversified engineering and contracting services to the energy industry, announces the completion of construction on the jackup drilling rig, “Al Gharbia”, and its delivery to Abu Dhabi’s National Drilling Company (‘NDC’). Completion and delivery of the jackup rig, on time and on budget, was marked at an inauguration ceremony held at Lamprell’s Hamriyah facility .... [+ read more] in the UAE on 22 December. The rig will depart the facility in late December en route to its drilling location in Abu Dhabi. The contract for the NDC “Al Gharbia” rig was signed in November 2014 and this is the seventh rig in a series of nine rigs being built and delivered by Lamprell to NDC. All nine rigs have been designed according to the Cameron LeTourneau Super 116E (Enhanced) Class design. The remaining two rigs are proceeding on schedule and will be delivered as planned in 2017.

21 Dec 2016

Audit of West Elara

The PSA has carried out an audit of North Atlantic Drilling in respect of structural safety at West Elara. West Elara is a jack-up drilling facility owned and operated by North Atlantic Drilling (NAD). The facility was issued with an Acknowledgement of Compliance (AOC) by the PSA in December 2011. The PSA has carried out an audit of the operational .... [+ read more] organisation for West Elara relating to competence within structural safety, the history of structural incidents and maritime systems, operational life assessments and routines for investigating structural incidents. The audit took place at NAD's premises in Bergen on 1 and 2 December 2016. The audit detected no non-conformities or improvement points.

21 Dec 2016

Drilling permit for well 16/2-22 S in production licence 265

The Norwegian Petroleum Directorate has granted Statoil Petroleum AS a drilling permit for well 16/2-22 S, cf. Section 8 of the Resource Management Regulations. Well 16/2-22 S will be drilled from the Deepsea Atlantic drilling facility in position 58°55’33.5’’ north and 2°24’33.2’’ east in a northwest extension of the Johan Sverdrup field in the central North Sea. The drilling programme .... [+ read more] for well 16/2-22 S concerns the drilling of an appraisal well on Johan Sverdrup in production licence 265. Statoil Petroleum AS is the operator with 40 per cent and the other licensees are Petoro AS with 30 per cent, Aker BP ASA with 20 per cent and Lundin Norway AS with 10 per cent. The area in this licence consists of part of block 16/2. The well will be drilled about 2 kilometres northwest of the 16/2-9 S well in the Tonjer West segment on Johan Sverdrup. Production licence 265 was awarded in on 24 April 2001 (North Sea Awards 2000). This is the 16th exploration well to be drilled in the licence area and the 12th exploration well on or near Johan Sverdrup in licence 265. The permit is contingent upon the operator having secured all other permits and consents required by other authorities before the drilling starts.

19 Dec 2016

Eni receives consent for exploration drilling in the Barents Sea

Eni has received consent to drill exploration well 7318/12-1 in the Barents Sea. Eni Norge AS (Eni) is the operator for production licence 716, in blocks 7318/11 and 7318/12 in the Barents Sea. Eni has received consent from the PSA to drill well 7318/12-11 in a prospect named Boné-Bigorna. The drilling location is around 320 kilometres north-west of Hammerfest. .... [+ read more] Water depth at the site is 418 metres. The drilling work is scheduled to take 55 days. The well is to be drilled using the Scarabeo 8 mobile facility, which is owned and operated by Saipem SpA. Scarabeo 8 was issued with an Acknowledgement of Compliance (AoC) by the PSA in May 2012.

19 Dec 2016

The World’s First R-550D Jack-Up Rig Is Successfully Delivered

On December 16th 2016, the Singapore based subsidiary of TSC Group Holdings Limited (“TSC”), Alliance Offshore Drilling Pte Ltd (“AOD”) has successfully taken delivery of the world’s first R-550D jack-up rig built by CSSC Huangpu Wenchong Shipbuilding Company Limited (“HPWS”) in Nansha District of Guangzhou. The historic milestone of the tri-party strategic cooperation between TSC, Zentech, Inc. (“Zentech”) and HPWS, achieves .... [+ read more] the reality of the initial blueprint and is set to significantly advance further into the future.

16 Dec 2016

Drilling permit for wellbore 7120/1-5 in production licence 492

The Norwegian Petroleum Directorate has granted Lundin Norway AS a drilling permit for wellbore 7120/1-5, cf. Section 8 of the Resource Management Regulations. Wellbore 7120/1-5 will be drilled from the Leiv Eiriksson drilling facility, at position 71°56' 15.97" north and 20°14' 57.37" east. The drilling programme for wellbore 7120/1-5 relates to the drilling of an appraisal well in production licence .... [+ read more] 492. Lundin Norway AS is the operator with an ownership interest of 40 per cent. The other licensee is Aker BP ASA with 60 per cent. The area in this licence consists of the blocks 7120/1 and 7120/2. The well will be drilled about four kilometres north of the 7120/1-3 discovery well in production licence 492. Production licence 492 was awarded on 29 February 2008 in APA 2007. The permit is contingent upon the operator securing all other permits and consents required by other authorities before commencing the drilling activities.

9 Dec 2016

New Crane for Kan Tan 7

The board (the “Board”) of directors (the “Directors”) of the Company is pleased to announce that pursuant to the terms of the New Master Agreement, TSC successfully secured an order for a deck crane and related service contracts (the “Contracts”) from Yantai CIMC Raffles Offshore Engineering Co. Ltd, which is a subsidiary of CIMC Raffles Offshore (Singapore) Limited (“CIMC Raffles”) recently. .... [+ read more] The deck crane will be installed on a 400ft jack-up rig owned by China Petrochemical Corporation (“Sinopec”) to replace an existing crane on Sinopec’s “Kantan 7” rig which is currently working in the South China Sea. The deck crane is scheduled to be delivered in mid of 2017. The deck crane is the TSC in-house designed model 198-200VE 60MT capacity Kingpost offshore deck crane manufactured to meet both ABS and CCS approvals. The replacement is approved by Sinopec indicates Sinopec’s recognition and trust in TSC’s offshore cranes. TSC was qualified as vendor to Sinopec in 2015 and has since provided two units of offshore deck cranes, various pump spare parts and technical services to Sinopec.

6 Dec 2016

Delivery Delay

Atwood Oceanics, Inc. (NYSE: ATW) announced today that it has agreed with Daewoo Shipbuilding & Marine Engineering Co. ("DSME") to delay the requirement to take delivery of Atwood's two newbuild ultra-deepwater drillships, the Atwood Admiral and the Atwood Archer, by two years to September 30, 2019 and June 30, 2020, respectively. In connection with the delay, Atwood will make a .... [+ read more] payment of $125 million for the Atwood Archer on or before December 15, 2016, as well as a payment of $15 million on the earlier of June 30, 2018 or the delivery date. In respect of the Atwood Admiral, Atwood will make a payment of $10 million on the earlier of September 30, 2017 or the delivery date. DSME will extend all remaining milestone payments, which include $83.9 million plus fees and interest for the Atwood Admiral and $165.0 million plus fees and interest for the Atwood Archer, until December 30, 2022. The Company's obligation to pay the remaining milestone payments will be evidenced by a promissory note executed by Alpha Admiral Company or Alpha Archer Company, each a subsidiary of the Company, on the date their respective drillship is delivered, with the note accruing interest at a rate of 5% per annum and being secured by a first preferred ship mortgage on the corresponding drillship. The Company has agreed not to terminate the construction contracts except in accordance with the terms of the supplemental agreements. The Company retains the option to take earlier delivery of each drillship, subject to a 45-day notice period to DSME, without affecting the final milestone payment date. Rob Saltiel, President and Chief Executive Officer, commented, "The restructuring of payment and delivery schedules for the Atwood Admiral and Atwood Archer is an important step in our capital structure management, enhancing liquidity and improving capital commitment timing. The two-year extensions on the delivery dates greatly improve our confidence that we will secure suitable drilling services contracts on both rigs prior to taking delivery. We now have the opportunity to earn revenues on these rigs that will cover some or all of the final payments to the shipyard. "We appreciate the flexibility that DSME has provided to Atwood Oceanics in response to this severe industry downturn." Mark Smith, Senior Vice President and Chief Financial Officer, added, "Our liquidity position is enhanced by approximately $250 million from June 30, 2018 until final payments are made to DSME on December 30, 2022. This lengthened time for making final milestone payments represents a staggering of our debt maturities. Following the December 15, 2016 payment, all interest expenses on the outstanding amounts due to DSME will be accrued and paid at the time of the final milestone payment, improving our free cash flows through 2022."

6 Dec 2016

Delivery Delay

Atwood Oceanics, Inc. (NYSE: ATW) announced today that it has agreed with Daewoo Shipbuilding & Marine Engineering Co. ("DSME") to delay the requirement to take delivery of Atwood's two newbuild ultra-deepwater drillships, the Atwood Admiral and the Atwood Archer, by two years to September 30, 2019 and June 30, 2020, respectively. In connection with the delay, Atwood will make a .... [+ read more] payment of $125 million for the Atwood Archer on or before December 15, 2016, as well as a payment of $15 million on the earlier of June 30, 2018 or the delivery date. In respect of the Atwood Admiral, Atwood will make a payment of $10 million on the earlier of September 30, 2017 or the delivery date. DSME will extend all remaining milestone payments, which include $83.9 million plus fees and interest for the Atwood Admiral and $165.0 million plus fees and interest for the Atwood Archer, until December 30, 2022. The Company's obligation to pay the remaining milestone payments will be evidenced by a promissory note executed by Alpha Admiral Company or Alpha Archer Company, each a subsidiary of the Company, on the date their respective drillship is delivered, with the note accruing interest at a rate of 5% per annum and being secured by a first preferred ship mortgage on the corresponding drillship. The Company has agreed not to terminate the construction contracts except in accordance with the terms of the supplemental agreements. The Company retains the option to take earlier delivery of each drillship, subject to a 45-day notice period to DSME, without affecting the final milestone payment date. Rob Saltiel, President and Chief Executive Officer, commented, "The restructuring of payment and delivery schedules for the Atwood Admiral and Atwood Archer is an important step in our capital structure management, enhancing liquidity and improving capital commitment timing. The two-year extensions on the delivery dates greatly improve our confidence that we will secure suitable drilling services contracts on both rigs prior to taking delivery. We now have the opportunity to earn revenues on these rigs that will cover some or all of the final payments to the shipyard. "We appreciate the flexibility that DSME has provided to Atwood Oceanics in response to this severe industry downturn." Mark Smith, Senior Vice President and Chief Financial Officer, added, "Our liquidity position is enhanced by approximately $250 million from June 30, 2018 until final payments are made to DSME on December 30, 2022. This lengthened time for making final milestone payments represents a staggering of our debt maturities. Following the December 15, 2016 payment, all interest expenses on the outstanding amounts due to DSME will be accrued and paid at the time of the final milestone payment, improving our free cash flows through 2022."

6 Dec 2016

Frigstad Offshore exits from investment

Frigstad Offshore exits from investment in Frigstad Deepwater newbuilds and positions itself for industry recovery Frigstad Deepwater Holding Ltd, a subsidiary of Frigstad Offshore Group, has decided to sell all of its shares in Frigstad Deepwater Ltd to a subsidiary of China International Maritime Containers Group (CIMC) with effect from 6 December 2016. Frigstad Deepwater Ltd, which has been jointly owned .... [+ read more] by Frigstad Offshore Group and CIMC since 2012, has two 7th generation ultra deepwater drilling units of the Frigstad D90™ design under construction at the Yantai CIMC Raffles shipyard in Shandong, China. The units, “Frigstad Shekou” and “Frigstad Kristiansand”, are scheduled for delivery in Q1-2017 and Q3-2017 respectively. As a consequence of the above, Frigstad Deepwater Ltd will become a wholly owned subsidiary of CIMC and be renamed “CIMC Bluewhale Rig Ltd”. The operational management of the rigs will be taken over by Bluewhale Offshore Pte Ltd, also a subsidiary of CIMC, and the rigs will be renamed “Bluewhale I” and Bluewhale II”. A team from Frigstad Offshore, the current manager of the rigs, will continue to supervise the construction of the two rigs until completion. Harald Frigstad, Chairman and founder of the Frigstad Group, says in a comment: “The ultra deepwater market has been extremely challenging for a while and we have agreed with CIMC that it is in the best interests of both parties that our group exit from the investment in Frigstad Deepwater Ltd at this moment. We are doing this on friendly terms and will remain a close partner of CIMC also in the future. Our exit from Frigstad Deepwater Ltd gives us a good foundation to position the Frigstad Group for the industry recovery which we believe will come. As part of this, we are reorganising the group and strengthening the organisation in key areas, which includes expansion at our office in Kristiansand, Norway. We are investing heavily in research and development, and will be launching the next generation of our ultra deep-water semi-submersible rig design in 2017 to keep up with industry requirements for new technology and higher efficiency. We strongly believe that offshore oil and gas will still play a very important role in the global energy supply for a long time, and we will be a part of this promising industry in the years to come, both as rig designer and drilling contractor.”

6 Dec 2016

Frigstad Offshore exits from investment

Frigstad Offshore exits from investment in Frigstad Deepwater newbuilds and positions itself for industry recovery Frigstad Deepwater Holding Ltd, a subsidiary of Frigstad Offshore Group, has decided to sell all of its shares in Frigstad Deepwater Ltd to a subsidiary of China International Maritime Containers Group (CIMC) with effect from 6 December 2016. Frigstad Deepwater Ltd, which has been jointly owned .... [+ read more] by Frigstad Offshore Group and CIMC since 2012, has two 7th generation ultra deepwater drilling units of the Frigstad D90™ design under construction at the Yantai CIMC Raffles shipyard in Shandong, China. The units, “Frigstad Shekou” and “Frigstad Kristiansand”, are scheduled for delivery in Q1-2017 and Q3-2017 respectively. As a consequence of the above, Frigstad Deepwater Ltd will become a wholly owned subsidiary of CIMC and be renamed “CIMC Bluewhale Rig Ltd”. The operational management of the rigs will be taken over by Bluewhale Offshore Pte Ltd, also a subsidiary of CIMC, and the rigs will be renamed “Bluewhale I” and Bluewhale II”. A team from Frigstad Offshore, the current manager of the rigs, will continue to supervise the construction of the two rigs until completion. Harald Frigstad, Chairman and founder of the Frigstad Group, says in a comment: “The ultra deepwater market has been extremely challenging for a while and we have agreed with CIMC that it is in the best interests of both parties that our group exit from the investment in Frigstad Deepwater Ltd at this moment. We are doing this on friendly terms and will remain a close partner of CIMC also in the future. Our exit from Frigstad Deepwater Ltd gives us a good foundation to position the Frigstad Group for the industry recovery which we believe will come. As part of this, we are reorganising the group and strengthening the organisation in key areas, which includes expansion at our office in Kristiansand, Norway. We are investing heavily in research and development, and will be launching the next generation of our ultra deep-water semi-submersible rig design in 2017 to keep up with industry requirements for new technology and higher efficiency. We strongly believe that offshore oil and gas will still play a very important role in the global energy supply for a long time, and we will be a part of this promising industry in the years to come, both as rig designer and drilling contractor.”

6 Dec 2016

Asset Sold for Scrap

The rig has been sold for scrap value. Sale price is in line with the net book value of the asset. .... [+ read more]

2 Dec 2016

Hercules Enters in to Sale Agreement for two Jackups

On December 2, 2016, Hercules British Offshore Limited (the “Seller”), a subsidiary of Hercules Offshore, Inc. (the “Company”), entered into a purchase and sale agreement (the “Purchase Agreement”) with Magni Drilling Limited (the “Buyer”). The Buyer is purchasing from the Seller two jack-up drilling rigs named Hercules Triumph (IMO 8771320) and Hercules Resilience (IMO 8771332) in their entirety, together with everything .... [+ read more] onboard, including all broached and unbroached provisions, spare parts and equipment onboard or onshore, rig site inventory, drawings, operating manuals, maintenance records, service contracts and all other documents pertaining to them for $130 million in cash. The Purchase Agreement is expected to close on or before January 10, 2017, subject to certain closing conditions.

2 Dec 2016

Hercules Enters in to Sale Agreement for two Jackups

On December 2, 2016, Hercules British Offshore Limited (the “Seller”), a subsidiary of Hercules Offshore, Inc. (the “Company”), entered into a purchase and sale agreement (the “Purchase Agreement”) with Magni Drilling Limited (the “Buyer”). The Buyer is purchasing from the Seller two jack-up drilling rigs named Hercules Triumph (IMO 8771320) and Hercules Resilience (IMO 8771332) in their entirety, together with everything .... [+ read more] onboard, including all broached and unbroached provisions, spare parts and equipment onboard or onshore, rig site inventory, drawings, operating manuals, maintenance records, service contracts and all other documents pertaining to them for $130 million in cash. The Purchase Agreement is expected to close on or before January 10, 2017, subject to certain closing conditions.

22 Nov 2016

Oil and gas discovery east of Johan Castberg in the Barents Sea - 7220/6-2 R

Lundin Norway AS, operator of production licence 609, has completed the drilling of wildcat well 7220/6-2 R. The well proved oil and gas. Well 7220/6-2 R is a deepening of well 7220/6-2, which was temporarily plugged and abandoned in November 2015. The well was drilled about 60 kilometres northeast of the oil and gas discovery 7220/11-1 (Alta) and about 20 kilometres .... [+ read more] east of 7220/8-1 Johan Castberg. The primary targets for the well were to prove petroleum in Middle Triassic sandstone rocks (Snadd formation) and in Permian to Carboniferous carbonate rocks (Ørn formation). The well encountered a total oil column of about 20 metres with an overlying gas column of about 10 metres in carbonate rocks in the Ørn formation, with good to moderate reservoir properties. In the Snadd formation, the well encountered aquiferous sandstone with moderate to good reservoir properties. Preliminary estimations of the size of the discovery range between 3 and 7 million standard cubic metres (Sm3) of recoverable oil and between 1 and 2 billion standard cubic metres of recoverable gas. The well was not production tested, but extensive data acquisition and sampling were carried out. The well is the sixth exploration well in production licence 609. The licence was awarded in the 21st licensing round in 2011. The well was drilled to a vertical depth of 1293 metres below the sea surface, and was terminated in basement rocks. Water depth is 387 metres. The well will now be permanently plugged and abandoned. Well 7220/6-2 R was drilled by the Leiv Eiriksson drilling facility, which will now proceed to production licence 533 in the Barents Sea to drill wildcat well 7219/12-1 where Lundin Norway AS is the operator.

22 Nov 2016

Fire on “Scarabeo 5”

On Tuesday 22 November at 1730 the drilling rig Scarabeo 5 reported a fire in an engine room. There are 106 personnel on board, all have been accounted for and no-one has been reported missing. Fire extinguishing is being carried out on the rig, which is located at the Njord field in the Norwegian Sea. The public rescue services .... [+ read more] and the authorities have been notified of the situation. Statoil’s emergency preparedness organisation has been mobilised and resources are being assembled to handle the incident. Personnel without emergency duties have been mustered to the lifeboat stations and preparations are being made to evacuate them by helicopter. No drilling operations were underway at the time of the incident. There are no other installations on the Njord field at the present time. A supply vessel is at the field and several more are underway. “Scarabeo 5” is a drilling rig operated by Saipem Norwegian Branch. Updates will be published on our website and via our news service.

22 Nov 2016

Fire on Scarabeo 5 put out

On Tuesday 22 November at 1730 the drilling rig Scarabeo 5 reported a fire in one engine room. Around 20:30 the fire was reported put out. There were 106 persons on board when the incident occurred; all of them are accounted for and none are missing. One person will be sent ashore for a medical check. 33 persons have been .... [+ read more] transported from the rig by helicopter. 14 of these were flown to a nearby installation and 19 to shore in Kristiansund. 73 persons remained on board and there are no plans currently to move more people from the rig. Work is under way to achieve normalization. Scarabeo 5 is currently located at the Njord-field in the Norwegian Sea. No drilling operations were underway when the incident occurred. The rig is equipped with two engine rooms and a total of eight engines. The standby vessels Ocean Response and Troms Sirius assisted the drilling rig. Three helicopters were in operation in connection with the incident. There are no other installations currently at the Njord field. Statoil’s second and third-line response organization has been mobilized to assist with the incident.

17 Nov 2016

Stena Don Stacked in Norway

Stena Drilling has selected Semco Maritime’s facilities at Hanøytangen for a warm stacking of the offshore drilling rig Stena Don. The rig will be warm stacked at the Hanøytangen yard in Bergen, ready for future work, explains Business Development Manager Øistein Tømte, Semco Maritime. Stena Don arrived at the yard 16 November and has previously been on a .... [+ read more] contract in the Troll field in the Norwegian sector of the North Sea. Stena Don is a class 3 semi-submersible rig built in 2001, and has recently been upgraded with a modern equipment package. The harsh environment rig is suitable for drilling, completion and workover operations worldwide. “Hanøytangen’s facilities include both wet dock and dry dock, which are tailored for assignments such as this where a rig arrives for a brief stopover, a Compliance Renewal survey or large-scale upgrade work before returning to operations,” says Øistein Tømte. The well-equipped dock facilities at Hanøytangen comprise several dock areas, including a dry dock of 116x125 meters and quay areas with depths of at least 100 meters. The dockyard is fitted with modern equipment for repair and handling of rigs, rig gear and other very large elements on water and land, including crane capacity at all docking areas.

8 Nov 2016

Consent to use Scarabeo 5 at Njord

Statoil has received consent to use Scarabeo 5 for well activities on the Njord field. Statoil is the operator at Njord, an oil field in the Norwegian Sea, located around 130 kilometres north of Kristiansund. The Njord field has been developed using a semi-submersible drilling, accommodation and production facility, Njord A, and the Njord B FSU. Water depth at the .... [+ read more] site is 330 metres. Production on the field began in 1997. The PSA has now granted Statoil consent to use Scarabeo 5 for various well activities associated with production wells on the field. The activities are scheduled to begin on 10 November 2016. Scarabeo 5 is a semi-submersible drilling facility of the ME 4500 type, built by Fincantieri in Genoa in 1990. It is registered in the Bahamas and classified by RINA/ABS. Scarabeo 5 was issued with an Acknowledgement of Compliance (AoC) by the PSA in May 2003.

4 Nov 2016

Delivery of Jackup

Lamprell (ticker: LAM), a leading provider of fabrication, engineering and contracting services to the energy industry, is pleased to announce the completion of construction of the "Ensco 141" jackup drilling rig and its delivery to Ensco Intercontinental GmbH, a subsidiary of Ensco plc ("Ensco").  The contract for the "Ensco 141" rig was signed in April 2014 and this is the second rig with the LeTourneau Super 116E (Enhanced) Class design which Lamprell has delivered to this leading drilling operator. The rig will be warm­stacked alongside its sister rig at Lamprell's stacking facility in Hamriyah, United Arab Emirates.  The Group currently has a further four new build jackup rigs under construction at its Hamriyah facility, which are progressing as planned and will be delivered over the coming 6 months. .... [+ read more]

31 Oct 2016

Songa Enabler suspended

Statoil will suspend the Songa Enabler contract when the current well on the Snöhvit field in the Barents Sea is completed, with the earliest estimate to be from the end of November 2016 according to the current drilling schedule. The expected resumption of drilling operations is currently the start of the Blåmann well 1 April 2017. Statoil is working to revise .... [+ read more] the existing drilling schedule with focus on an earliest possible date for resumption of work. The rig will go on 75% suspension rate (USD 343.000 per day). The Company will minimize the overall financial impact through the suspension period with reduced manning and reduced activity level.

19 Oct 2016

Historic Bedout Sub-basin flow test

Carnarvon Petroleum Limited (“Carnarvon”) (ASX:CVN) advises that the Roc-2 well test successfully flowed gas and condensate to surface over the course of a sustained test program. Quadrant Energy, as operator of the permit, undertook controlled flow test operations in the Roc-2 well. The well flow tested at rates up to 51.2 million scf per day of gas and 2,943 barrels of .... [+ read more] condensate per day, that is approximately 11,500 barrels of oil equivalent* per day. These rates were achieved through an approximate 1 1/2” choke and were equipment constrained flow rates; meaning the well flowed at the maximum rate possible in the equipment being used. Testing operations were undertaken at controlled flow rates to enable the monitoring of the field including reservoir pressures, gas and condensate ratios and the presence of other substances such as CO2, H2S, water and sand. Encouragingly, there were insignificant levels of these other substances in the gas and condensate recorded during the flow test.

18 Oct 2016

Two minor gas/condensate/oil discoveries in the Norwegian Sea - 6407/7-9 S and 6407/7-9 A

Statoil Petroleum AS, operator of production licence 107 C, has completed the drilling of wildcat wells 6407/7-9 S and 6407/7-9 A. The wells were drilled about six kilometres north of the Njord field in the southern part of the Norwegian Sea and about 137 kilometres north of Kristiansund. The primary exploration target for the wells was to prove petroleum in .... [+ read more] Early and Middle Jurassic reservoir rocks (Ile and Tilje formation) and the secondary exploration target was to prove Early Jurassic reservoir rocks (Åre formation). Well 6407/7-9 S encountered a 102-metre oil column in the Ile formation, and a 157-metre gas/condensate column in the Tilje formation. The reservoir properties in both reservoirs are poor to moderate. The well did not encounter a reservoir in the Åre formation. A few thin sand layers were encountered in the Lange formation in the Cretaceous, some with petroleum, but with poor reservoir properties. Preliminary estimates place the size of the discovery between 0.2 and 3 million standard cubic metres (Sm3) of recoverable oil equivalents. Well 6407/7-9 A encountered a 195-metre gas column in the Tilje formation and a 140-metre gas column in the Åre formation. Mobile petroleum was not proven in the Ile formation. The reservoir properties in the reservoirs are poor to moderate. Preliminary estimates place the size of the discovery between 0.1 and 1.5 million standard cubic metres (Sm3) of recoverable oil equivalents. The licensees will consider the discoveries along with other nearby discoveries with regard to a development with tie-in to the Njord field. The wells were not formation-tested, but extensive data acquisition and sampling were carried out. The wells are the first two exploration wells in production licence 107 C. The licence was awarded in APA 2008. Wells 6407/7-9 S and 6407/7-9 A were drilled to measured depths of 4114 metres and 4931 metres below the sea surface, respectively, and vertical depths of 4105 metres and 4127 metres below the sea surface, respectively. Both wells were terminated in the Åre formation from the Early Jurassic Age. Water depth is 323 metres. The wells will now be permanently plugged and abandoned. Wells 6407/7-9 S and 6407/7-9 A were drilled by the Songa Delta drilling facility, which will now proceed to a plugging operation on Tune in production licence 190.

17 Oct 2016

Gas/condensate discovery northeast of the Martin Linge field in the North Sea - 30/4-3 S

Total E & P Norge, operator of production licence 043, is in the process of completing the drilling of wildcat well 30/4-3 S. The well was drilled in the northeast part of the Martin Linge field. The objective of the well was to prove petroleum in Middle Jurassic reservoir rocks (Brent group). The well encountered gas and condensate in .... [+ read more] the Tarbert, Ness and Etive formations in the Brent group. Reservoir quality was good. Preliminary estimations of the size of the discovery are between 2 and 11 million standard cubic metres (Sm3) of recoverable oil equivalents. Extensive data acquisition and sampling have been carried out. The well was formation-tested. The maximum production rate was 2.4 million standard cubic metres (Sm3) of gas/flow day through a 48/64-inch nozzle opening. The well has added additional resources to the Martin Linge development and was completed with the objective of putting the well into production at start-up of the field. 30/4-3 S is the fourth exploration well in production licence 043. The licence was awarded in 1976. The well was drilled to a vertical and measured depth of 4134 metres and 4581 metres below the sea surface, respectively, and was terminated in the Dunlin group in the Early Jurassic. Water depth is 115 metres. The well was drilled with the Mærsk Intrepid drilling facility.

15 Oct 2016

Well incident at Songa Endurance

On Saturday 15 October a well control incident occurred on the drilling rig Songa Endurance. The well has now been secured with a blowout preventer around the drill string on the seabed and with a valve on the rig. Work is now being carried out to stabilise the well. Personnel without work assignments in connection with the incident will now .... [+ read more] be removed from the rig. The incident was reported to the company’s alarm centre at 9:50 am CET on Saturday. There were 107 people on board when the incident occurred. No injuries were reported and there is no risk of an oil spill. Songa Endurance was working on the G4 well in the Troll field near Troll B when complications arose. Complications occurred during the work on removing the production string from the well. The blowout preventer was then activated and the well is now closed. There is still pressure in the well and work is now being carried out to stabilise the well. Fluid for stabilising the well is being sent out to the rig from land to be able to perform this work. These supplies are expected to arrive at the field at around 8 pm CET this evening. Extra specialist personnel are on the way to the rig to assist those on board. Statoil and Songa Offshore have mobilised their emergency response organisations. The emergency response vessel Stril Merkur is at the field and other resources, including helicopters, are available. Weather conditions are good. The Troll field is located in the northern part of the North Sea, approximately 65 kilometres west of Kollsnes in Hordaland. The field extends over an area of 750 square kilometres in blocks 31/2, 31/3, 31/5 and 31/6 in the North Sea.

14 Oct 2016

Maersk Drilling names fourth and final XLE jack-up rig

Maersk Drilling’s fourth XL Enhanced ultra harsh environment jack-up was named Friday morning at a ceremony held at the Daewoo Shipbuilding and Marine Engineering (DSME) shipyard in South Korea. Mrs. Bente Norheim, wife of Jan Norheim, Managing Director of BP Norge, honoured Maersk Drilling by naming the rig Maersk Invincible. Maersk Invincible is the fourth and final rig in a .... [+ read more] series of four ultra harsh environment jack-up rigs to enter Maersk Drilling’s fleet. The four jack-up rigs represent a total investment of USD 2.6bn. The first three jack-up rigs have been delivered from the Keppel FELS shipyard, while the Maersk Invincible will be delivered from DSME later in 2016. After delivery from the yard, Maersk Invincible will mobilise to the North Sea and commence a five year firm contract with BP Norge for plug and abandonment work on the Valhall field in the Norwegian North Sea. The estimated contract value for the firm contract is USD 812 million, including mobilisation from South Korea to Norway, but excluding cost escalation. “With the naming of our fourth XLE jack-up, we are nearing the end of a newbuilding era for Maersk Drilling. Maersk Invincible will be the final XLE rig to enter our fleet. These highly advanced drilling rigs enable us to provide safe and efficient drilling operations to our customers on the Norwegian market and with the addition of Maersk Invincible, we will further strengthen our market leading position in Norway,” says Claus V. Hemmingsen, CEO of Maersk Drilling and Vice CEO of the Maersk Group, and continues: “We look forward to working closely together with BP Norge on the Valhall field. I am confident that Maersk Invincible will live up to her name when she commences operation.”

30 Sep 2016

Deepening of appraisal well 7220/11-3 A in the Barents Sea – 7220/11-3 AR

Lundin Norway AS, operator of production licence 609, has completed drilling the deepening 7220/11-3 AR on the 7220/11-1 (Alta) oil and gas discovery. The well was drilled about four kilometres south of the 7220/11-1 discovery well. The 7220/11-1 discovery was proven in October 2014 in carbonate rocks dating from the Early Triassic to the Carboniferous. The operator’s resource estimate after .... [+ read more] drilling the discovery well was between 14 and 50 million standard cubic metres (Sm3) of recoverable oil and between 5 and 17 billion Sm3 of recoverable gas. Well 7220/11-3 AR is a deepening of the 7220/11-3 A appraisal well, which was temporarily plugged and abandoned in September 2015. 7220/11-3 A was drilled to a measured depth of 2105 metres and a vertical depth of 1962 metres below the sea surface, and was terminated in the Gipsdalen Group in the Permian. The objective of well 7220/11-3 AR was to continue exploring the reservoir properties in the Ørn and Falk Formations under the oil-water contact in the discovery. The well encountered several zones with very good reservoir properties. Two injection tests have been completed, with injection rates of 800 and 2900 Sm3 of seawater per flow day in the Falk and Ørn Formations, respectively. A production test was also carried out in the gas zone in the Lower Triassic, with a production rate of 595 000 Sm3 gas per flow day through a 64/64 inch nozzle opening. Pressure data from the 7220/11-3, 7220/11-3 A appraisal wells and deepening 7220/11-3 AR indicate communication with the 7220/11-1 discovery well. Extensive data and samples have been collected from all wells. The results from the appraisal wells are important with regard to the further work on mapping the eastern flank of the discovery. The resource estimate will be reassessed based on the new data. This is a deepening of the fifth well in production licence 609. The licence was awarded in the 21st licensing round in 2011. The 7220/11-3 AR deepening was drilled to a measured depth of 2575 metres and a vertical depth of 2389 metres below the sea surface, and was terminated in Carboniferous sandstone in the Gipsdalen Group. Water depth is 397 metres. The well was drilled by the Leiv Eiriksson drilling facility, which will now proceed to drill wildcat well 7220/6-2 R in the same production licence.

30 Sep 2016

Delivery of jackup rig to Shelf Drilling

Lamprell (ticker: LAM), a leading provider of fabrication, engineering and contracting services to the energy industry, is pleased to announce the completion of construction of the "Shelf Chaopraya" jackup drilling rig and its delivery to Shelf Drilling Ltd. ("Shelf").  The rig will sail within the next few days for deployment by Shelf at its drilling location, offshore Thailand. The "Shelf Chaopraya" has been designed according to the LeTourneau Super 116E (Enhanced) Class design and features high specification offshore drilling technology, as well as accommodation for up to 160 people. With this delivery, the Lamprell Group has now completed and delivered a total of 16 Super 116E new build jackup drilling rigs to our clients. .... [+ read more]

20 Sep 2016

Drilling permit for well 7219/12-1 in production licence 533

The Norwegian Petroleum Directorate has granted Lundin Norway AS a drilling permit for well 7219/12-1, cf. Section 8 of the Resource Management Regulations. Well 7219/12-1 will be drilled from the Leiv Eiriksson drilling facility at position 72°12' 44.2" north and 19°46' 38.3" east. The drilling programme for well 7219/12-1 relates to the drilling of a wildcat well in production licence .... [+ read more] 533. Lundin Norway AS is the operator with an ownership interest of 35 per cent. The other licensees are Det norske oljeselskap ASA with 35 per cent and DEA Norge AS with 30 per cent. The area in this licence consists of blocks 7219/12 and 7220/10. The well will be drilled about 24 kilometres south of the discovery well 7220/10-1 in production licence 533. Production licence 533 was awarded on 15 May 2009 in the 20th licensing round on the Norwegian shelf. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

16 Sep 2016

Gas and oil discovery northeast of the Gjøa field in the North Sea – 36/7-4

ENGIE E&P Norge AS, operator of production licence 636, is in the process of completing the drilling of wildcat well 36/7-4. The well proved oil and gas. The well was drilled six kilometres northeast of the Gjøa field and 55 kilometres southwest of Fløro. The objective of the well was to prove petroleum in Early Cretaceous reservoir rocks (Agat formation). .... [+ read more] The well encountered an approx. 50-metre gas column and 60-metre oil column in the Agat formation. Reservoir quality ranges from very good in the top section to good in the lower section. Preliminary estimation of the size of the discovery is between 4.3 – 11 million standard cubic metres (Sm3) of recoverable oil equivalents. The well was formation-tested. The maximum production rate was 1.3 million Sm3 gas per flow day through a 76/64-inch nozzle opening. The gas/oil ratio is approx. 16,000 Sm3/Sm3. The formation test generally showed very good production and flow properties. Extensive data and samples were collected. The licensees will consider a tie-in of the discovery to existing infrastructure on the Gjøa field. 36/7-4 is the first exploration well in production licence 636. The licence was awarded in APA 2011. The well was drilled to a vertical depth of 2702 metres below the sea surface, and was terminated in the Åsgard formation in the Lower Cretaceous. Water depth at the site is 349 metres. The well will now be permanently plugged and abandoned. The well was drilled with the Transocean Arctic drilling facility.

16 Sep 2016

Gas and oil discovery northeast of the Gjøa field in the North Sea – 36/7-4

ENGIE E&P Norge AS, operator of production licence 636, is in the process of completing the drilling of wildcat well 36/7-4. The well proved oil and gas. The well was drilled six kilometres northeast of the Gjøa field and 55 kilometres southwest of Fløro. The objective of the well was to prove petroleum in Early Cretaceous reservoir rocks (Agat formation). .... [+ read more] The well encountered an approx. 50-metre gas column and 60-metre oil column in the Agat formation. Reservoir quality ranges from very good in the top section to good in the lower section. Preliminary estimation of the size of the discovery is between 4.3 – 11 million standard cubic metres (Sm3) of recoverable oil equivalents. The well was formation-tested. The maximum production rate was 1.3 million Sm3 gas per flow day through a 76/64-inch nozzle opening. The gas/oil ratio is approx. 16,000 Sm3/Sm3. The formation test generally showed very good production and flow properties. Extensive data and samples were collected. The licensees will consider a tie-in of the discovery to existing infrastructure on the Gjøa field. 36/7-4 is the first exploration well in production licence 636. The licence was awarded in APA 2011. The well was drilled to a vertical depth of 2702 metres below the sea surface, and was terminated in the Åsgard formation in the Lower Cretaceous. Water depth at the site is 349 metres. The well will now be permanently plugged and abandoned. The well was drilled with the Transocean Arctic drilling facility.

15 Sep 2016

Minor oil discovery near the Vega field in the North Sea – 35/11-19 S, 35/11-20 S, 35/11-20 A and 35/11-20 B

Wintershall Norge AS, operator of production licence 248 F, is in the process of completing the drilling of four wells in the North Sea. The wells are wildcat well 35/11-20 S, appraisal well 35/11-20 A and wildcat well 35/11-20 B. Due to technical issues, well 35/11-19 S had to be abandoned, and well 35/11-20 S was drilled about 50 metres southwest .... [+ read more] of 35/11-19 S. Well 35/11-20 A was classified as a wildcat well, but will now be reclassified as an appraisal well. The wells were drilled about five kilometres southeast of the Vega field in the North Sea and 100 kilometres southwest of Florø. The primary and secondary exploration targets for well 35/11-20 S were to prove petroleum in Late Jurassic reservoir rocks (intra Heather formation sandstone). The well did not encounter reservoir rocks in the primary exploration target. The well encountered an 8-metre oil column in the secondary exploration target at the top of an intra Heather formation sandstone with poor reservoir quality and a total thickness of about 70 metres. The objective of well 35/11-20 A was to delineate the oil discovery in intra Heather formation sandstone, and to prove petroleum in Middle Jurassic (Brent group) and Early Jurassic (Cook formation) reservoir rocks. The well encountered a total oil column of 33 metres in intra Heather formation sandstone, of which 19 metres were of good reservoir quality. Due to technical issues, it was not possible to reach the Brent group and Cook formation. Well 35/11-20 B was drilled to further delineate the oil discovery in intra Heather formation sandstone. The secondary target was to prove petroleum in Middle Jurassic (Brent group) and Early Jurassic (Cook formation) reservoir rocks. The well encountered a total oil column of 46 metres in intra Heather formation sandstone, of which 29 metres were of moderate reservoir quality. A total oil column of 19 metres was encountered in the Tarbert formation in the Brent group, of which 10 metres were of moderate reservoir quality. The Cook formation was encountered with a total thickness of about 170 metres with predominantly poor reservoir quality and only traces of petroleum. Preliminary estimates place the size of the discovery between 1.5 and 4.5 million standard cubic metres (Sm3) of recoverable oil equivalents. The licensees will evaluate the discovery along with other nearby discoveries with a view toward a potential development. The wells have not been formation-tested, but extensive data and samples were collected. The wells are the second, third, fourth and fifth exploration wells in production licence 248 F. Wells 35/11-20 S and 35/11-20 A were drilled to respective measured depths of 3553 and 3943 metres below the sea surface and respective vertical depths of 3437 and 3293 metres below the sea surface. Both wells were terminated in the Heather formation in the Middle Jurassic. Well 35/11-20 B was drilled to measured and vertical depths of 5083 metres and 4055 metres below the sea surface, respectively, and was terminated in the Statfjord group in the Early Jurassic. Water depth at the site is 373 metres. The wells will now be permanently plugged and abandoned. Wells 35/11-19 S, 35/11-20 S, 35/11-20 A and 35/11-20 B were drilled by the Borgland Dolphin drilling facility.

14 Sep 2016

http://www.t-s-c.com/news/group-news/harmoni-victory-jack-up-named-one-of-two-indonesian-flagged-rigs/

Harmoni Victory (ZENTECH R-550D 400ft Jack-up Rig) was recently re-invited to bid in a formal tender for PHE ONWJ (Offshore North West Java in Indonesia) estimated term contract 1+1 year. While over 13 contractors are registered for pre-qualification, of which only two bidders passed the pre-qualification based on the justification of Cabotage Law (PM 200 Year 1015). It was re-tendered as .... [+ read more] there wasn’t enough quorum in initial round. In accordance with SKK MIGAS Regulation PTK-007, Operator can choose to directly select the bidder in the second round process. Notably, Harmoni Victory is one of these rigs, which presents a strong competitive advantage for securing future work in Indonesia. Harmoni Victory is also pursuing other tender opportunities to support Indonesia operators with a costs-efficient rig, operated by mainly local experienced rig crew. The Rig is the process of obtaining permits SIOPSUS from Ministry of Sea Transportation (DEPHUBLA) and have recently completed equipment worthiness inspection (SKPI) conducted by third party inspection team and witnessed by DITJEN MIGAS.

9 Sep 2016

Dry well northwest of the Ekofisk field in the North Sea - 1/5-5

Total Norge AS, operator of production licence 618, is in the process of completing the drilling of wildcat well 1/5-5. The well is dry. The well was drilled about 40 kilometres northwest of the Ekofisk field and 320 kilometres southwest of Stavanger. The primary exploration target for the well was to prove petroleum in Upper Jurassic reservoir rocks (Ula formation). .... [+ read more] The secondary exploration target was to prove petroleum in Upper Triassic reservoir rocks (Skagerrak formation). The well encountered about 80-metre thick sandstone in the Ula formation with moderate to poor reservoir quality. The reservoir only contains traces of gas. The well is classified as dry. Data acquisition was carried out. This is the first exploration well in production licence 618. The licence was awarded in APA 2011. Well 1/5-5 was drilled to a vertical depth of 5942 metres below the sea surface and was terminated in the Bryne formation in the Middle Jurassic. Water depth at the site is 70 metres. The well will now be plugged and abandoned. Well 1/5-5 was drilled with the Maersk Gallant drilling rig.

5 Sep 2016

Drilling permit for wellbore 25/2-18 A in production licence 442

The Norwegian Petroleum Directorate has granted Det norske oljeselskap ASA a drilling permit for well 25/2-18 A, cf. Section 8 of the Resource Management Regulations. Well 25/2-18 A will be drilled from the Maersk Interceptor drilling facility, at position 59°49'30.11"N and 2°37'54.1"E in production licence 442. The drilling programme for well 25/2-18 A relates to the drilling of an appraisal .... [+ read more] well. Det norske oljeselskap ASA is the operator with an ownership interest of 90 per cent and LOTOS Exploration and Production Norge AS is a licensee with a 10 per cent ownership interest. The area in this licence constitutes a part of block 25/2 and 25/3. Production licence 442 was awarded in APA 2006, on 15 June 2007. This is the second well to be drilled within the licence. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

30 Aug 2016

Lundin receives consent for exploration drilling

Lundin Norway AS has received consent for exploration drilling in the Barents Sea. Lundin Norway AS (Lundin) is the operator for production licence 533, comprising blocks 7219/12 and 7220/10 in the Barents Sea. The PSA has given Lundin consent to drill exploration well 7219/12-1 in a prospect named Filicudi. The drilling site is 218 kilometres north-west of Hammerfest. Water depth .... [+ read more] is around 320 metres. Drilling is scheduled to begin in early September and will last 59 days, with an addition for a potential well test. The well is to be drilled using the Leiv Eiriksson mobile facility, which is owned and operated by Ocean Rig. The facility is a BINGO 9000 type, built in 2001. It is classified by DNV GL and registered in the Bahamas. Ocean Rig received Acknowledgement of Compliance for Leiv Eiriksson from the PSA in July 2008.

25 Aug 2016

Mærsk Gallant drills to record depths on Norwegian shelf

With a total depth of 5,941 metres, Mærsk Gallant has beaten the record for deepest well ever drilled on the Norwegian continental shelf. On 31 July, Mærsk Gallant drilled the Solaris ultra HPHT (high-pressure, high-temperature) well to a total depth of 5,941 metres TVD (True Vertical Depth). This means that Mærsk Gallant has beaten the record for deepest well .... [+ read more] ever drilled on the Norwegian continental shelf. "We have broken a number of records during the Solaris operation. But this achievement is second to none. There was a lot of cheering in the driller's cabin that day," says Sadi Ozturk, Assistant Rig Manager on Mærsk Gallant. He continues: "The Solaris exploration well is one of the most challenging wells in the North Sea. All crew members are very excited about this achievement." In the Solaris project – together with the customer, Total E&P Norge – Maersk Drilling has taken a 15,000 psi rig and adapted the equipment and procedures in order to drill a reservoir section where predicted pore pressures are well in excess of 15,000 psi. The demanding requirements of the customer have led to a wide variety of modifications on the rig.

22 Aug 2016

Seadrill Receives Notice of Contract Cancellation for the West Pegasus

Seadrill Limited ("SDRL" or "the Company") has received a notice of termination from Pemex Exploracion y Servicios ("Pemex") for the West Pegasus drilling contract (the "Contract") effective 16 August 2016. Seadrill has disputed the grounds for termination and is reviewing its legal options. During the second quarter of 2015 Seadrill signed a provisional commitment for a two .... [+ read more] year extension to the Contract with Pemex for the West Pegasus. In conjunction with the extension, the dayrate for the remaining term of the initial contract was reduced. The extension of the Contract was finalized during the first quarter of 2016. As part of this agreement, Seadrill and Seamex Limited ("Seamex"), our 50% owned joint venture with Fintech, agreed to reduce the dayrate on five jack-ups for a period of 365 days. The agreement to reduce the dayrates of the existing contracts was contingent upon final confirmation of the two year extension of the West Pegasus by Pemex management. In the event of termination, Seadrill and Seamex are entitled to recover the dayrate concessions as well as the demobilization for the West Pegasus. In addition, Seadrill will seek reimbursement of certain costs incurred in anticipation of the extension.

22 Aug 2016

Bollsta Dolphin Settlement

Fred. Olsen Energy ASA and Hyundai Heavy Industries Co., Ltd. ("HHI") are pleased to announce that they have resolved by commercial agreement their disputes and differences arising in connection with the newbuilding contract for the construction of the semi-submersible drilling platform "Bollsta Dolphin". Ownership of the platform will be retained by HHI and the arbitration proceedings associated with the disputes .... [+ read more] have been terminated by consent. All of the claims that have been asserted by the parties have been withdrawn and Bollsta will receive about MUSD 176, 4 from HHI of the first instalment paid by Bollsta. In a joint statement, the parties said: "We are very pleased that our differences have been resolved in an amicable way.”

19 Aug 2016

Arrival of jackup rigs

Semco Maritime is pleased to welcome the recent arrival of two Maersk Drilling high specification jack-up rigs to our Invergordon ship-yard facility. Maersk Reacher will be berthed in our Queens Dock facility for an undisclosed duration, carrying out necessary upgrades and modifications, whilst the recently constructed Maersk Highlander, following arrival by heavy lift from Singapore, will be at quayside for .... [+ read more] a short time, carrying out various commissioning tasks prior to naming ceremony and thereafter, mobilization out to the CULZEAN development in the UK sector North Sea, on long term contract. Semco Maritime Rig Projects have provided support for various disciplines, including electrical, mechanical and construction, with a number of safety instrumented systems provided by Semco Maritime as original equipment during the construction of the rig being commissioned, prior to departure. The Cromarty Firth and Invergordon Service Base was chosen as most suitable for both of these assets due to its strategic location in the North sea, with deep water shelter, the facilities offered by Port of Cromarty Firth and a long standing relationship with Semco Maritime as main contractor, providing full project management support to Maersk Drilling. Semco Maritime are also nearing completion of a number of scopes of work for the semi-submersible rig, Paragon MSS1, prior to departing Cromarty Firth on a drilling contract.

18 Aug 2016

Maersk Highlander Named

Lady Sponsor Gretchen H. Watkins, COO at Maersk Oil, has named Maersk Drilling’s newest asset at a ceremony at Invergordon, Scotland. Maersk Highlander is now ready for the job. Maersk Highlander was named yesterday at a ceremony at Invergordon, Scotland. Maersk Drilling CEO and member of the Executive Board of The Maersk Group, Claus V. Hemmingsen, gave the commemorative .... [+ read more] speech in front of prominent guests from Maersk Oil, BP, JX Nippon, Jurong Shipyard and the local community. Maersk Highlander will soon start operations in the Culzean gas field in the North Sea where it will work for Maersk Oil and partners JX Nippon and BP. "I think we have acquired a very fine piece of equipment, a little sister to our XLE rigs," Said Claus. V. Hemmingsen in front of the large crowd. The 400ft newbuild has been at the Port of Cromarty Firth in Invergorden, Scotland, since she was transported from the Jurong Shipyard in Singapore. The harsh environment jack-up rig was acquired from a subsidiary of Hercules Offshore before delivery from the yard. Lady sponsor was Gretchen H. Watkins, COO at Maersk Oil. She stated that the contract stands testimony to the strong ties between Maersk Oil and Maersk Drilling: "Maersk Oil and Maersk Drilling share constant care as a core value and we have a tightly aligned approach to safety and employee welfare. We are confident we have a drilling partner which will meet our expectations for industry leading operational performance, and do it whilst putting safety first." Said Gretchen Watkins. Claus V. Hemmingsen highlighted recent years' significant fleet growth within Maersk Drilling: the acquisition of four deepwater drillships and four ultra-harsh environment jack-ups in response to the increasing demand for new rigs in an ever-evolving industry. Now the tide has turned and a new oil reality has arrived. However, opportunities can emerge even when facing adverse market conditions. "This rig was not originally part of our growth plans, nor was she ours from the outset. However, the opportunity of acquiring this rig and adding her to our fleet seemed obvious to us as she came with a firm long-term contract with a well-known customer and partners," Said Claus V. Hemmingsen. He admitted that it might seem a difficult challenge to take in a brand new rig in the middle of a severe industry downturn. "But in the 40+ year history of Maersk Drilling, it is far from an unknown challenge to take a new, state-of-the-art piece of drilling equipment into operation," Said Claus. V. Hemmingsen. Maersk Highlander will work on a five-yeacontract valued at approx. USD 420m, including a mobilization fee of USD 9m.

18 Aug 2016

Contract Termination

Ensco plc has received a notice of termination for convenience from Total for the ENSCO DS-7 drillship. The effective date of the termination will be early during the fourth quarter of 2016. According to Ensco plc’s announcement, the contractor does not anticipate ‘a material impact to its financial results for 2016 and 2017 as a result of this termination’. .... [+ read more]

16 Aug 2016

Njord North Flank-2 exploration well commences drilling in the Norwegian Se

Faroe Petroleum, the independent oil and gas company focusing principally on exploration, appraisal and production opportunities in Norway and the UK, is pleased to announce the commencement of the Njord North Flank-2 (“NF-2”) exploration well 6407/7-9 S (Faroe 7.5%). The NF-2 prospect is located in Licence PL107C immediately north of the Njord field (Faroe 7.5%). The well will target .... [+ read more] Middle and Lower Jurassic sandstone reservoirs of the Ile and Tilje formations in a fault-bounded structural closure, with a TD in the Lower Jurassic Åre Formation. If successful, NF-2 could add further reserves and value to the Njord Future Project. The NF-2 exploration well, located in approximately 323 metres of water, is operated by Statoil Petroleum AS (20%) using the Songa Delta drilling rig, with co-venturers ENGIE E&P Norge AS (40%), DEA E&P Norge AS (30%) and VNG Norge AS (2.5%). Results from the well will be announced when drilling operations have been completed.

15 Aug 2016

Consent to use Maersk Interceptor at Ivar Aasen

Det norske has received consent to use Maersk Interceptor to drill production wells at Ivar Aasen. 15.08.2016 Print Tip someone Register for news Ivar Aasen is an oil and gas field in the North Sea, around 175 kilometres west-south-west of Karmøy in Rogaland county. Water depth in the area is approximately 110 metres. Det norske is the field's .... [+ read more] operator. The field has been developed using a Production/Drilling/Quarters (PDQ) facility with a steel jacket. Drilling of the wells for the PDQ is being done from a jack-up facility with a cantilever drilling rig. Det norske has received consent from the PSA to use the Maersk Interceptor jack-up drilling rig to drill production wells for Ivar Aasen PDQ. Wells have previously been drilled using another rig. It is provisionally planned for Maersk Interceptor to drill a further three wells. Drilling is scheduled to start in late November and estimated to last until 1 July 2017. Maersk Interceptor was delivered by the Keppel Shipyard of Singapore in 2014. The facility is owned by Maersk AS and operated by Maersk Drilling Norge AS. Maersk Interceptor was issued with an Acknowledgement of Compliance (AoC) by the PSA in December 2014.

15 Aug 2016

WA-320-P DRIFTWOOD-1 FINAL DRILLING UPDATE

Tap Oil Limited (ASX:TAP) provides the following update on the WA-320-P permit in which it holds a 9.778% participating interest. The WA-320-P permit is located in the Carnarvon Basin, offshore Western Australia and the Driftwood-1 commitment well is located in WA-320-P in the Barrow sub-basin of the Northern Carnarvon Basin, approximately 1km north of the Rosily-1A exploration well which had minor .... [+ read more] oil shows. The well was spudded at 13:00 hrs WST on 1 August 2016 with the Noble Tom Prosser jackup drilling rig in 100.8 metres of water and was drilled to a final total depth of 2,111 metres measured depth at 14:20 hrs on 12 August 2016. The well objective was to test the Early Cretaceous sandstones of the Mardie Greensand Member, Birdrong Member and Zeepaard Formation in a low-relief, northeast-southwest trending four-way dip closure. The well intersected all of the drilling objectives, however all were water wet. There were no hydrocarbon shows intersected in the primary and secondary targets, elevated gas readings were noted from 2,055 metres measured depth to total depth of the well. The plan for the next 24 hrs is to recover the 30 inch surface conductor and to release the rig the afternoon of 16 August 2016.

13 Aug 2016

Tam Dao 05 Jack Up Rig Handover Ceremony

On 12 August 2016, Russia-Vietnam Joint Venture - Vietsovpetro (Vietsovpetro) as owner and PetroVietnam Marine Shipyard (PV Shipyard) as the builder held handover ceremony for the Tam Dao 05 jack up rig after 32 months of construction. Tam Dao 05 is a jack-up rig, designed in accordance with Friede and Goldman’s JU-2000E model. It is expected to have a total .... [+ read more] 18,000 tonnage when it is built, capable of operating at a depth of 120 meters or 400 ft below water, and will be able to drill at a depth of 9,000 meters, or 30,000 ft. This is the second jack-up rig domestically manufactured by subsidiaries of PetroVietnam. The first was Tam Dao 03 which was put into operation in 2012.

10 Aug 2016

Heavy lift completes Semco Maritime rebuilding of Maersk Guardian

A 147-room complete hotel module will today be lifted on board the Maersk Guardian to finalize a major conversion of the upcoming hotel rig. Following design and construction of a turnkey accommodation module with 147 chambers and appertaining facilities for accommodation rig Maersk Guardian, Semco Maritime is now preparing the final installation just 8 months after the order was placed. The .... [+ read more] module, which has been built and outfitted by Semco Maritime and its collaboration partners in Gdynia, Poland, was loaded onto a barge last week to be sailed to Frederikshavn, Denmark. Here the 1,200-ton module will be lifted and installed on board Maersk Guardian today and tomorrow by a floating crane, which arrived from Kiel Tuesday. According to Vice President Nikolaj Vejlgaard, Semco Martime has never constructed an accommodation block this size before. "The heavy lifting marks the final and intense part of the project, where the modules are to be installed and hooked-up on the rig. Combined with additional modifications of the rig performed simultaneously with the module construction, the former jack-up rig can now be approved and used as a hotel rig", says Vejlgaard.

8 Aug 2016

ISDS first for DNV GL classed Ocean Greatwhite - world’s largest semi-submersible

DNV GL has welcomed the world’s largest semi-submersible drilling rig into class recently. Ocean Greatwhite is 123 metres long and 78 metres wide and was delivered at Hyundai Heavy Industries in Ulsan, South Korea. Owned by the Houston-based drilling contractor Diamond Offshore, the rig will be chartered to oil major BP and will operate in the Great Australian Bight. The rig .... [+ read more] is to be a new design MOSS CS60E high specification state-of- the art semi-submersible drilling unit suitable for operations in harsh environments, which is the first MOSS CS60E and the largest rig in the world. “The Ocean GreatWhite is a unique rig purposely built for drilling in harsh environments,” said Karl Sellers, SVP Technical Services at Diamond Offshore. “HHI and DNV GL were integral in helping us get this rig to market as we prepare for the drilling project in Australia with BP.” “We have a strong relationship with both DNV GL and Diamond Offshore – and it is thanks to this good cooperation that the project went so well. We are proud to deliver the first drilling ship of this size and look forward to many more projects on this scale,” Youngseuk Han, Senior Executive Vice President at HHI said. “We will keep moving the boundaries of technology by completing following large-scale and innovative projects.” “Ocean Greatwhite is capable of operating in depths of up to 3000 metres and can drill down to a depth of 10,670 metres. It represents the state of the art in the semi-submersible sector and we are very pleased to have been asked to contribute our expertise to this project,” says Paal Johansen, Vice President and Regional Director, Americas at DNV GL. Ocean Greatwhite is also the first new-build rig to receive the DNV GL Integrated Software Dependent Systems (ISDS) notation. ISDS are systems whose performance is dependent on the overall behaviour of their integrated software components. DNV GL’s ISDS standard helps owners and operators minimise software integration errors and delays in projects involving complex integrated systems. The certification ensures that software and integration issues are identified and resolved early on during the project design stages. It also represents a new approach to verification, as it emphasises a review of the working methods and processes that lead to the delivery the systems, rather than simply focusing on the final review of documents and installations to ensure they meet product requirements. Industry data suggests that high specification mobile offshore drilling units may experience 30 per cent down-time during their first years of operations, which makes a systematic framework for ensuring that ISDS achieve the required reliability, availability, maintainability and safety essential. “We expect that the operational performance of Ocean Greatwhite will demonstrate how the ISDS notation can contribute to increasing the reliability of the complex systems onboard,” adds Paal Johansen. DNV GL’s ISDS teams in Korea, Norway, and the USA all contributed to the project. DNV GL also provided advisory services to HHI on the integration of the various systems throughout the newbuilding process.

8 Aug 2016

Drilling permit for well 35/11-20 B in production licence 248 F

The Norwegian Petroleum Directorate has granted Wintershall Norge AS a drilling permit for well 35/11-20 B, cf. Section 8 of the Resource Management Regulations. Well 35/11-20 B will be drilled from the Borgland Dolphin drilling facility, at position 61°13’20.32’’ north 03°26’25.45’’ east following the completion of drilling of wildcat well 35/11-20 A for Wintershall Norge AS in production licence 248 F. .... [+ read more] The drilling programme for well 35/11-20 B relates to the drilling of a wildcat well in production licence 248 F. Wintershall Norge AS is the operator with an ownership interest of 40 per cent. The other licensees are Origo Exploration Norway AS (20 per cent) and Petoro AS (40 per cent). The area in this licence consists of a part of block 35/11. The well will be drilled about 100 kilometres southwest of Florø and about 20 kilometres northwest of the Fram field. Production licence 248 F was carved out of production licence 248 on 10 December 2015. Production licence 248 was awarded on 4 June 1999 (North Sea Awards 1999). This is the third well to be drilled within the licence. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

4 Aug 2016

Dry well north of the Hanz discovery in the North Sea - 25/10-15 S

Det norske oljeselskap AS, operator of production licence 626, has completed the drilling of wildcat well 25/10-15 S. The well is dry. The well was drilled in the central part of the North Sea, about six kilometres north of the Hanz discovery and 200 kilometres northwest of Stavanger. The primary exploration target for the well was to prove .... [+ read more] petroleum in Upper Jurassic reservoir rocks (intra Draupne sandstone). The secondary exploration target was to prove petroleum in Middle Jurassic reservoir rocks (Hugin formation). The well encountered a 36.5-metre thick sandstone in the Upper Jurassic with moderate to poor reservoir quality and an 11-metre thick Middle Jurassic sandstone with good to moderate reservoir quality. The well also encountered a 65-metre thick Skagerrak formation with moderate reservoir quality. The well is dry. Data acquisition has been carried out. Well 25/10-15 S was drilled to a measured depth of 2696 metres (MD RT) and a vertical depth of 2629 metres below the sea surface. The well was terminated in basement of unknown age. This is the first exploration well in production licence 626. The licence was awarded in APA 2011. Water depth is 117 metres. The well will now be permanently plugged and abandoned. Well 25/10-15 S was drilled by the Mærsk Interceptor drilling facility, which will now proceed to drill wildcat well 25/2-18 S in production licence 442, where Det norske oljeselskapet AS is the operator.

4 Aug 2016

Dry well northeast of Johan Castberg in the Barents Sea - 7222/1-1

Eni Norge AS, operator of production licence 226, is in the process of completing the drilling of wildcat well 7222/1-1. The well is dry. The well was drilled about 80 kilometres northeast of the Johan Castberg oil field and about 250 kilometres north of Hammerfest. The objective of the well was to prove petroleum in Middle Triassic (Kobbe formation) and .... [+ read more] Permian (Ørn formation) reservoir rocks. Secondary targets were Late Triassic (Snadd formation) and Permian (Røye formation) reservoir rocks. The well encountered 22 metres of poor quality sandstone reservoir with traces of gas in the Kobbe formation. The well was terminated before it reached the Ørn formation. Two aquiferous sandstone reservoirs (Carn and Ladin) were encountered in the Snadd formation, 56 and 18 metres, respectively. They both had moderate reservoir quality. An 18-metre aquiferous carbonate reservoir with poor reservoir quality was encountered in the Røye formation. Extensive data acquisition and sampling have been carried out. This is the first wildcat well in production licence 226, which was awarded on 30 May 1997 in the Barents Sea project. Well 7222/1-1 was drilled to a vertical depth of 2366 metres below the sea surface and was terminated in the Røye formation from the Permian Age. Water depth is 424 metres. The well will now be permanently plugged and abandoned. The well was drilled by the Scarabeo 8 drilling facility.

3 Aug 2016

Consent to use Songa Enabler at Snøhvit

Statoil has received consent to use Songa Enabler for drilling three wells at Snøhvit. Snøhvit is a gas field in the Barents Sea north-west of Hammerfest. Statoil is the field's operator. Snøhvit has been developed using a subsea production facility. The gas is transported onshore through a 143-kilometre-long pipeline to Melkøya, off Hammerfest. Production at Snøhvit began in 2007. Gas .... [+ read more] from the field contains CO2, which is separated out at Melkøya and sent back to the field for reinjection. Statoil has received consent to use the Songa Enabler mobile drilling facility to drill three wells on the field. Two of these are production wells, while the third is for reinjecting CO2. The wells are designated 7121/4 G-4 H, F-1 H and G-3 H. The two well templates are in 316 and 318 metres of water respectively. Drilling is scheduled to begin in late July 2016 and will last for 220 days in all. Songa Enabler is a semi-submersible drilling facility of the CAT D type. It was delivered by the Daewoo yard in South Korea in 2016, is registered in Norway and classified by DNV-GL. Songa Enabler was issued with an Acknowledgement of Compliance (AoC) by the PSA in July 2016.

2 Aug 2016

Det norske receives consent for exploration drilling

Det norske has received consent for exploration drilling in production licence 442 in the North Sea. Det norske has taken over the operatorship for production licence 442 from Centrica. The PSA has given Det norske consent to drill an exploration well in a prospect named Langfjellet. The location is around 134 kilometres west of Austevoll in Hordaland county. Water depth .... [+ read more] is 122 metres. The activity is scheduled to begin in August 2016 and will last between 31 and 80 days depending on whether a discovery is made. The well will be drilled using the Maersk Interceptor mobile drilling facility, operated by Maersk Drilling Norge AS. The facility was delivered by the Keppel FELS Shipyard in Singapore in 2014. It is registered in Singapore and classified by DNV GL. Maersk Interceptor was issued with an Acknowledgement of Compliance (AoC) by the PSA in December 2014.

2 Aug 2016

Consent to use Songa Delta at Tune

Statoil has received consent to use Songa Delta for well plugging at Tune. The Tune field is a gas and condensate field in the North Sea, around 10 kilometres west of the Oseberg field centre. Statoil is the field's operator. Water depth at the site is around 95 metres. The field has been developed using a subsea template and a satellite .... [+ read more] well tied back to Oseberg. Production at Tune began in 2002. Statoil has now received consent to use the Songa Delta mobile drilling facility to plug well 30/8-A-12 on the field permanently. The activity is scheduled to begin in early September 2016 and estimated to last 24 days. Songa Delta is operated by Songa Offshore. It was issued with an Acknowledgement of Compliance (AoC) by the PSA in November 2012.

1 Aug 2016

Aqualis Offshore oversees transport of world’s largest jack-up rig

Marine and offshore engineering consultancy Aqualis Offshore has been contracted by Noble Corporation to oversee the load-on, transportation and load-off operations of the first journey of the world’s largest jack-up rig, the Noble Lloyd Noble. Aqualis Offshore’s scope of work includes providing marine warranty services for the load-on, transportation and load-off operation of the giant jack-up. Aqualis Offshore will .... [+ read more] ride with the ship for the first leg of the journey from Singapore to Port Elizabeth, South Africa. The rig’s ultimate destination is Statoil’s Mariner field development in the UK sector of the North Sea. Contract value is undisclosed.

29 Jul 2016

Songa Enabler commencement of drilling contract

Songa Enabler has commenced drilling operations on 29 July 2016 in the Barents Sea. The rig is now on operating rate under its eight-year drilling contract with Statoil on the Norwegian continental shelf. Songa Enabler is the last rig in a series of four Category D semi-submersible drilling rigs, specifically built for and contracted to Statoil. .... [+ read more]

29 Jul 2016

Drilling for replenishment of Snøhvit gas

The Songa Enabler drilling rig has started drilling a new injection well for CO2 gas on the Snøhvit field off the coast of Hammerfest. Next a production well will be drilled for replenishment of gas for Hammerfest LNG. Snøhvit is still the only LNG project in the world capturing and storing CO2 separated from the well stream in a dedicated formation .... [+ read more] offshore. So far more than four million tonnes of CO2 from Snøhvit have been stored. The stored CO2 is being monitored in order to ensure that it does not mix with the main producing reservoir. A new CO2 injection well is now required. After the new CO2 injector is installed, the rig will move on to drill the first new production well at Snøhvit since the field came on stream in 2007. The drilling campaign is planned to last until Christmas. The CO2 solution project was established in 2013 in order to build and install a new CO2 injection well, replacing the original injector that over time would leak CO2 into the gas reservoir on the Snøhvit field. “Hammerfest LNG needed replenishment of gas in order to maintain the high production and capacity utilisation at the plant, while ensuring sustainable CO2 storage. This project is therefore important to Statoil,” says Geir Owren, asset owner representative for the project. In the summer of 2015 an extensive marine campaign was performed. Pipelines and a template for the CO2 project were installed and tied in to the existing subsea facility on the Snøhvit field. The new subsea facility was built and installed without injuries and well within the budget of NOK 2.5 billion. “The distance to the Barents Sea presents extra challenges with regard to mobilisation and sailing time, which requires careful planning, thorough preparations and close cooperation with the suppliers. We are pleased both with the equipment suppliers and marine operations, which resulted in successful project implementation,” says project leader Sveinung Øvretveit. The next big development step for Hammerfest LNG is the development of the Askeladd field, which is part of the plan for development and operation of the Snøhvit licence. It is expected to come on stream in 2020/2021. This development step will help ensure full utilisation of the capacity at Hammerfest LNG.

28 Jul 2016

Maersk Valiant contract cancelled

An early termination agreement for the deepwater unit Maersk Valiant has been signed by Maersk Drilling and ConocoPhillips and Marathon Oil with effect from mid-September 2016. Maersk Valiant has been on a joint contract with Marathon Oil Corporation and ConocoPhillips since June 2014. The original contract was scheduled to end September 2017. The compensation under the early termination agreement leaves Maersk .... [+ read more] Drilling financially neutral to the original contract. “With the termination of Maersk Valiant, we are reminded of the extremely challenging conditions in the offshore oil and gas market. It is with regret that we will see a high performing rig such as the Maersk Valiant without work, but we will continue to explore opportunities with our customers and seek ways to create innovative solutions to enable project viability,” says Head of Global Sales, Michael Reimer Mortensen. Maersk Valiant was built in 2014 and is equipped with dual BOPs as well as an integrated MPD system. The Rig is designed for year-round operation in areas such as the Gulf of Mexico, West and East Africa and Asia Pacific at water depths of up to 3,600 m (12,000 ft.).

28 Jul 2016

Shell announces Fort Sumter discovery in Gulf of Mexico

Shell today announced a new exploration discovery in the deep water U.S. Gulf of Mexico. The initial estimated recoverable resources for the Fort Sumter well are more than 125 million barrels of oil equivalent (boe). Further appraisal drilling and planned wells in adjacent structures could considerably increase recoverable potential in the vicinity of the Fort Sumter well. “The Fort Sumter .... [+ read more] discovery builds upon Shell’s global deep-water leadership. Its proximity to our nearby discoveries in the area, and to highly prospective acreage to the southeast, makes Fort Sumter particularly significant,” said Ceri Powell, Executive Vice President Exploration. “These successes demonstrate there is still running room in the producing basins of our heartlands where large, high-value discoveries have the potential to further strengthen our deep-water competitiveness.” Fort Sumter was safely drilled in the Mississippi Canyon Block 566, located approximately 73 miles (117 kilometers) offshore southeast of New Orleans, in a water depth of 7,062 feet (2,152 metres) to a total vertical drilling depth of 28,016 feet (8,539 metres) measured depth. The block is nine square miles (23 square kilometers) in size and is operated by Shell (100%). An appraisal sidetrack well was later drilled to a depth of 29,200 feet (8,900 metres) measured depth. Shell’s material discovery in this heartland builds upon recent Norphlet exploration success at the Appomattox (2010), Vicksburg (2013), and Rydberg (2014) discoveries, bringing the total resources added by exploration in the Gulf of Mexico for Shell since 2010 to around 1.3 billion boe. Shell global deep water, which is a growth priority for the company, currently produces around 600 thousand boe per day, and production is expected to increase to about 900 thousand boe per day by the early 2020s from already discovered, established reservoirs.

27 Jul 2016

Drilling permit for well 25/2-18 S in production licence 442

The Norwegian Petroleum Directorate has granted Det norske oljeselskap ASA a drilling permit for well 25/2-18 S, cf. Section 8 of the Resource Management Regulations. Well 25/2-18 S will be drilled from the Maersk Interceptor drilling facility at position 59°49’30.03’’ north, 02°37’54.14’’ east. The drilling programme for well 25/2-18 S relates to the drilling of a wildcat well in production .... [+ read more] licence 442, where Det norske oljeselskap ASA is the operator with an ownership interest of 90 per cent. The other licensee is Lotos Exploration and Production Norge AS with 10 per cent. The area in this licence consists of parts of blocks 25/2 and 25/3. The well will be drilled in the south-eastern part of the licence, which is located in the central North Sea. Production licence 442 was awarded on 15 June 2007 (APA 2006). This is the second exploration well to be drilled in the licence, but the fourth within the area where the licence is situated. The permit is conditional on the operator securing all other permits and consents required by other authorities prior to commencing the drilling activity.

26 Jul 2016

Drilling permit for well 7220/6-2 R in production licence 609

The Norwegian Petroleum Directorate has granted Lundin Norway AS a drilling permit for well 7220/6-2 R, cf. Section 8 of the Resource Management Regulations. Well 7220/6-2 R will be drilled from the Leiv Eiriksson drilling facility at position 72° 34' 13.1" north and 20° 58' 19.66" east. The drilling programme for well 7220/6-2 R relates to an extension of previous .... [+ read more] wildcat well 7220/6-2, drilled in 2015 in production licence 609. Lundin Norway AS is the operator with a 40 per cent ownership interest, and the licensees are Idemitsu Petroleum Norge AS with 30 per cent and DEA Norge AS with 30 per cent. The production licence consists of blocks/parts of blocks 7220/6, 7220/9, 7220/11, 7220/12 and 7221/4. The production licence was awarded in the 21st licensing round in 2011. Wildcat well 7220/6-2 R will be an extension of the sixth exploration well in production licence 609. The permit is contingent on the operator securing all other permits and consents required by other authorities prior to commencing the drilling activity.

26 Jul 2016

ALE 30,000t load-out uses unique skidding system

ALE completed the load-out of the first 30,000t CAT-J jack-up rig in July, using a unique skidding system especially designed for the project. ALE completed the load-out of the first jack-up rig for the CAT-J project at the Samsung Heavy Industries Shipyard in South Korea. The jack-up rig, which weighed more than 30,000t, was built on top of supports .... [+ read more] on a concrete track 20m from the quayside. ALE used their own unique, self-propelled skidding system and ballasting system to load-out the jack-up rig from the quay onto a floating drydock barge. 76 skid shoes, each equipped with a 650t capacity jack, were installed underneath the rig. By extending these cylinders, the load was transferred from the building supports onto the skidding system. The three-point hydraulic suspension was created in order to control and check the stability of the system during the load-out. The ALE ballast system was installed beside the internal ballast system of the floating drydock itself. This provided sufficient ballasting capacity for the tide during the load-out and was used to compensate the barge the load was transferred from the skidding system.

21 Jul 2016

Lundin Petroleum commences the 2016 southern Barents Sea drilling campaign

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that its wholly owned subsidiary Lundin Norway AS (Lundin Norway) has commenced the 2016 exploration and appraisal campaign in the Loppa High area in the southern Barents Sea with the winterised Leiv Eiriksson semi-submersible drilling rig. The 2016 drilling campaign consists of three wells commencing with the re-entry of the Alta-3 appraisal .... [+ read more] well 7220/11-3A in PL609 which was successfully drilled last year on the eastern flank of the Alta discovery. The objective of the Alta-3 re-entry is to deepen the well to further assess the quality of the Permian carbonate reservoir section as well as to conduct a production test. The original Alta-3 well encountered a gross hydrocarbon column of 120 metres and all three Alta wells drilled to date have proven pressure communication. The Alta discovery is estimated to contain gross contingent resources of between 125 and 400 million barrels of oil equivalents (MMboe). Following the completion of the Alta-3 well the rig will move further north on PL609 to re-enter the suspended Neiden exploration well 7220/6-2 which was partially drilled last year. The Neiden well was suspended immediately above prognosed reservoir section in October last year due to winter restrictions for the drilling rig (Island Innovator). The Neiden prospect is estimated to contain gross unrisked prospective resources of 204 MMboe. The third well to be drilled in the 2016 campaign is an exploration well targeting the Filicudi prospect on PL533 to the northwest of the Alta discovery and south of the Statoil operated Johan Castberg discovery. The Filicudi prospect is expected to contain Jurassic sandstone reservoir analogous to the Johan Castberg discovery. The Filicudi prospect is estimated to contain gross unrisked prospective resources of 258 MMboe. Lundin Norway is the operator of both PL609 and PL533 and holds a 40 percent and 35 percent working interest in these respective licences. The Leiv Eiriksson drilling rig has been contracted for three firm well slots with an additional six optional well slots.

21 Jul 2016

Seco 702 Held for Sale

According to Transocean’s latest fleet status report (July 2016), the deepwater floater, Sedco 702, is held for sale and will be recycled in an environmentally responsible manner. .... [+ read more]

20 Jul 2016

Acknowledgement of Compliance for Songa Enabler

Songa Offshore has received the PSA's Acknowledgement of Compliance (AoC) for Songa Enabler. Songa Enabler is a semi-submersible facility and the fourth of the Cat D rigs that Songa is building for Statoil. 20.07.2016 Print Tip someone Register for news Songa Enabler is a semi-submersible facility and the fourth of the Cat D rigs that Songa is building .... [+ read more] for Statoil. In total, 60 mobile facilities have received an Acknowledgement of Compliance from the PSA. It is the PSA's assessment that petroleum activities may be carried out using the Songa Enabler facility within the regulatory framework. The validity of the Acknowledgement of Compliance assumes that Songa Offshore ensures that the facility and relevant parts of the company’s organisation and management systems are maintained, to fulfil the terms and conditions set out in the PSA’s decision. In connection with the AoC application for Songa Enabler, the PSA carried out audits within several selected disciplines.

20 Jul 2016

Skipper Update

Independent Oil and Gas plc ("IOG" or the “Company”), the development and production focused Oil and Gas Company, is pleased to provide an update on the drilling of the appraisal well on the Skipper oil discovery which lies in Block 9/21a in licence P1609 in the Northern North Sea. The Skipper appraisal well, of which IOG is 100% owner and .... [+ read more] operator, will be drilled by Transocean’s Sedco 704 semi-submersible drilling rig which is now on contract with IOG and is being towed to the drilling location. Operations are anticipated to commence on 22 July 2016. Further to the announcements on 7 December 2015 and 11 December 2015, the loan agreements signed with GE Oil & Gas UK Limited for £2 million and London Oil & Gas Limited, part of London Group plc for £2.75 million and £0.8 million have been extended to 20 December 2017, in line with a number of other service and equipment contractors on deferred payment terms for all or part of their costs on the Skipper well. No fees have been levied or further warrants granted in achieving this extension. It was previously announced on 14 July 2016 that from 19 July 2016, the number of Ordinary Shares in issue would be 101,546,680. The correct amount is 101,728,498 Ordinary Shares and this number should be used by shareholders going forward as the denominator for the calculations by which they will determine if they are required to notify their interest in, or a change to their interest in the Company under the FCA’s Disclosure and Transparency Rules.

19 Jul 2016

Engie spuds Cara

ENGIE E&P Norge is the operator of the exploration well PL 636 Cara in the northern North Sea. The Cara well is located 35 kilometres from shore and approximately 6 kilometres from Gjøa in the Northern North Sea. Water depth is about 350 meters and both oil and/or gas cases are considered. The well is regarded a standard exploration well of .... [+ read more] conventional design with a four string casing program. The drilling rig Transocean Arctic will be conducting the drilling operation. The Transocean Arctic, operated by Transocean Norway Operations AS, is a harsh environment midwater semi-submersible drilling rig. The drilling operation is scheduled to take approximately 41 days. In case of discovery, the plan is to execute a Drill Stem Test for an additional 25 days to assess the size of the reservoir. "In case of a commercial discovery, Cara is a potential tie-back to the Gjøa-platform, which we operate. The results from Cara will increase our understanding of the Gjøa area, which is one of our core areas on the Norwegian Continental Shelf," says Cedric Osterrieth, Managing Director of ENGIE E&P Norge AS. The Norwegian Petroleum Directorate will announce the result of the drilling operation.

17 Jul 2016

Newbuild Delivery

Hyundai Heavy Industries (HHI), the world’s largest shipbuilder and a leading offshore facilities manufacturer, today announced it delivered Ocean Greatwhite, the world’s largest semi-submersible drilling rig, to Diamond Offshore, a Houston-based drilling contractor on July 15. The delivery installment worth 460 billion won ($395 million) HHI received from the client will help improve HHI’s cash flow. Ocean .... [+ read more] Greatwhite, measuring 123 m in length and 78 m in width, is capable of operating in waters up to 3 km deep and drilling down to a depth of 10.67 km from the sea surface. The rig will be chartered to BP for operation in the Great Australian Bight from October this year. HHI won the order worth $630 million to build the rig in 2013 and has delivered four other drillships to the US-based drilling contractor so far. An HHI official said, “The close cooperation between Diamond Offshore and HHI on the basis of mutual trust is what made the delivery of Ocean Greatwhite possible.”

16 Jul 2016

Sembcorp Marine delivers Noble Lloyd Noble, the world’s largest jack-up rig, to Noble Corporation

Sembcorp Marine, a global leader in offshore and marine engineering solutions, has delivered the world’s largest jack-up rig to Noble Corporation. Noble Lloyd Noble, the seventh ultra high-specification harsh environment jack-up rig successfully completed for Noble Corporation, is based on the GustoMSC CJ70 design as well as Statoil’s ‘Category J’ specifications. The rig has an operational air gap .... [+ read more] of 69 metres and is capable of operating in a water depth of up to 150 metres (492 feet) in harsh environmental conditions. It boasts a maximum total drilling depth capacity of 10,000 metres (approximately 33,000 feet). To be deployed in Statoil’s Mariner field development in the North Sea under a four-year charter arrangement, Noble Lloyd Noble is the first offshore structure of its kind to fully comply with both Norwegian and UK regulatory standards. It is uniquely suited for operation over a very large platform or in a subsea configuration. The Noble Lloyd Noble project achieved 8 million man-hours worked without reportable incidents onboard the rig. It also scored a low Accident Frequency Rate (AFR) of 0.10 per million man-hours worked over a 31-month construction period. Sembcorp Marine President and CEO Wong Weng Sun said: “The Noble Lloyd Noble reaffirms Sembcorp Marine’s ability to continuously scale new peaks as a manufacturer of the world’s most sophisticated rigs. With a global network of facilities, we are able to execute projects of any scale and complexity to high health, safety and environmental standards. We look forward to partnering with Noble Corporation again in building the best and most versatile offshore structures.”

14 Jul 2016

Keppel AmFELS delivers fifth jackup rig to Perforadora Central

Keppel AmFELS LLC, a wholly owned subsidiary of Keppel Offshore & Marine Ltd (Keppel O&M) in the U.S., has delivered Uxpanapa, a KFELS B Class jackup rig, to Mexico's Central Panuco S.A. De C.V. (Central Panuco), a subsidiary of Mexico's Perforadora Central S.V. De C.V. on time and within budget. The rig was christened yesterday at Keppel AmFELS' yard in .... [+ read more] Brownsville, Texas by the owners of Central Panuco. Uxpanapa is the the fifth jackup rig built by Keppel AmFELS for Perforadora Central and the second based on Keppel's proprietary KFELS B Class design. Mr Simon Lee, President of Keppel AmFELS, said at the ceremony, "The delivery of this fifth jackup rig to Central Panuco to their highest satisfaction is a result of our close partnership backed by the yard's strong capabilities. We are proud to be Central Panuco's choice shipyard as they grow their fleet of rigs to be a premier rig operator in the region. "As the most established shipyard in the Gulf of Mexico, we are able to understand and meet the needs of our customers. Our strong position in the gulf coupled with our execution expertise enable us to support rig owners in the region with a wide variety of solutions, including newbuilds, repairs and conversions." Uxpanapa will be chartered by PEMEX, the Mexican national oil company, for work in offshore Mexico. Keppel AmFELS' past collaboration with PEMEX includes having built two 220 Men accommodation modules for Pemex in 2006, as well as repairing and servicing a total of 18 rigs for various drilling operators that have been chartered by PEMEX over the years. Mr Patricio Alvarez Morphy Orvañanos, Senior Vice President of Central Panuco added, "We are pleased to receive the Uxpanapa, another high quality jackup rig from Keppel AmFELS on time and on budget. In the current challenging market conditions, oil companies such as PEMEX prefer highly cost-efficient and reliable equipment such as the KFELS B Class jackup rig which has a proven track record operating in Mexico. The Tonala, our current KFELS B Class jackup, has been performing outstandingly for PEMEX. "As we grow our presence in the Gulf of Mexico, we are glad to be able to count on Keppel AmFELS as our preferred yard in providing excellent services and offshore rig solutions that are well-regarded by our customers." Keppel AmFELS previously completed Tonala, an ultra premium KFELS B Class jackup, for Perforadora Central in 2004, followed by three LeTourneau S116E rigs, namely Tuxpan in 2010, Papaloapan in 2013 and Coatzacoalcos in 2014. As a group, Keppel O&M is the leading rig provider to the Mexican market, having delivered 16 projects, including this latest rig, with another four on order for Mexico.

14 Jul 2016

Skipper Update

Drilling of the Skipper appraisal well, of which IOG is 100% owner and operator, is anticipated to commence on 22 July 2016 and will be drilled by Transocean’s Sedco 704 semi-submersible, which is expected to come on contract on or around 20 July 2016. Skipper lies in Block 9/21a in licence P1609 in the Northern North Sea and IOG is .... [+ read more] the 100% owner and the appraisal well is expected to take approximately 22 days to drill. The vertical well will be drilled to 5,600ft with the primary objective of retrieving good quality reservoir condition oil samples in order to optimise the Skipper field development plan. The well will also drill two mapped reservoir structures beneath the Skipper oil field in the Lower Dornoch and Maureen formations. The directors of the Company believe an approved field development plan on Skipper would convert the Board’s estimated 34.1 MMBbls of contingent resources, based on a 25% recovery factor, into 2P reserves. Initial results from the well are expected mid-August.

13 Jul 2016

Oil and gas discovery south of the Brage field in the North Sea - 31/7-1 and 31/7-1 A

Faroe Petroleum Norge AS, operator of production licence 740, has concluded the drilling of wildcat well 31/7-1 and appraisal well 31/7-1 A. 31/7-1 proved oil and gas and 31/7-1 A delineated the discovery. The wells were drilled 13 kilometres south of the Brage field in the North Sea. The primary exploration target for the wells was to prove and .... [+ read more] delineate petroleum in Middle Jurassic reservoir rocks (the Fensfjord formation). The secondary exploration target was also in Middle Jurassic reservoir rocks (the Brent group) and the third exploration target was in the Lower Jurassic (the Cook formation and the Statfjord group). 31/7-1 encountered a gas column of about 18 metres and an oil column of about 21 metres in sandstone in the Middle Jurassic Fensfjord formation. Reservoir quality is good. Well 31/7-1 A, which delineated the discovery, encountered a gas column of 6 metres and an oil column of 25 metres at levels equivalent to those of the discovery well. The secondary and third exploration targets were dry. Preliminary estimates indicate that the size of the discovery is between 6.8 and 12.7 million standard cubic metres (Sm3) of recoverable oil equivalents. The wells were not formation-tested, but extensive data acquisition and sampling have been carried out. The licensees will assess tie-in of the discovery to existing infrastructure on the Brage field. The wells are the first and second exploration wells in production licence 740, which was awarded in APA 2013. Well 31/7-1 was drilled to a vertical depth of 2750 metres below the sea surface, and was terminated in the Statfjord group in the Lower Jurassic. Well 31/7-1A was drilled to a vertical depth of 2270 metres below the sea surface, and was terminated in the Fensfjord formation in the Middle Jurassic. Water depth at the site is 140 metres. The wells will now be permanently plugged and abandoned. The wells were drilled by the Transocean Arctic drilling facility, which will now drill wildcat well 36/7-4 in production licence 636 in the North Sea, where ENGIE E&P Norge AS is the operator.

11 Jul 2016

Roc-2 well commences drilling

Carnarvon Petroleum Limited (“Carnarvon”) (ASX:CVN) is pleased to report that the operator of the Roc-2 well, Quadrant Energy, has advised that the well commenced drilling on 9 July 2016. The main aims of the Roc-2 well are to appraise the Roc gas-condensate discovery in the Caley section that Carnarvon announced on 4 January 2016, to progress towards proving a volume above .... [+ read more] the minimum economic field size and to establish potential flow rates for future development planning. Secondary objectives for the well are to explore the hydrocarbon potential of the deeper Milne member, where encouraging hydrocarbon shows were observed during the final phase of drilling the Roc-1 well, and the shallower Huxley member, where oil shows were encountered at Roc-1. The Roc-2 well will be drilled in around 100m water depth, approximately 160 km north-east of Port Hedland in the Bedout sub-basin of the greater Roebuck basin (figures 1 and 2). The well will take approximately 60 days to drill down to a total depth of around 5,250 metres, including the cutting of 120 metres of core, before the evaluation program is undertaken. The evaluation, including wireline logging and flow testing, is expected to extend over a further 40 days.

11 Jul 2016

Dry well south of the Johan Sverdrup oil field in the North Sea – 16/5-6

Tullow Oil Norge AS, operator of production licence 776, is in the process of completing the drilling of wildcat well 16/5-6. The well is dry. The well was drilled approximately 30 kilometres south of the Johan Sverdrup oil field in the central part of the North Sea and about 200 kilometres west of Stavanger. The objective of the well was .... [+ read more] to prove petroleum in reservoir rocks from the Upper Jurassic (the Draupne formation). The well did not encounter sandstone in the Draupne formation. Approx. 100 metres of tight rock and 10 metres of aquiferous sandstone of poor reservoir quality were encountered in the Skagerrak formation from the Triassic. Data has been acquired. This is the first exploration well in production licence 776, awarded in APA 2014. Well 16/5-6 was drilled to a vertical depth of 2319 metres below the sea surface and was terminated in rocks from the Triassic Age (Skagerrak formation). Water depth at the site is 98 metres. The well will now be permanently plugged and abandoned. Well 16/5-6 was drilled by the Borgland Dolphin drilling facility, which is now scheduled to drill wildcat well 35/11-20 A in production licence 248 F in the North Sea, operated by Wintershall Norge AS.

11 Jul 2016

Hercules Offshore, Inc. Announces Agreement to Sell the Hercules 267 by Hercules International Drilling Ltd.

Hercules Offshore, Inc. (OTC Pink: HEROQ) announced today that its subsidiary, Hercules International Drilling Ltd., entered into an agreement to sell the Hercules 267 to an undisclosed buyer for $3.16 million. The sale is expected to close imminently, subject to the satisfaction of customary closing conditions. .... [+ read more]

8 Jul 2016

AAL G Sand appraisal well operations complete

AWE Limited (ASX: AWE) advises that all operations relating to the AAL-4XST1 appraisal well have been completed and the Raniworo jack-up drilling rig was released on 7 July 2016. The AAL-4XST1 appraisal well successfully drilled and intersected the primary G Sand and secondary K Sand targets. Both reservoirs are of excellent quality and were fully cored for further analysis. Drill Stem .... [+ read more] Tests (DSTs) were performed on both reservoirs and oil flowed successfully to surface, assisted by Electrical Submersible Pumps (ESPs) which is standard procedure in heavy oil fields due to the viscosity of the oil. Logging of the well has been completed and the well has been plugged and abandoned according to Production Sharing Contract (PSC) requirements. The well program was completed within the Operator’s budget. As previously reported, the G Sand DST was conducted over a 3.5m perforated interval and exceeded expectations with an average stabilised flow rate of 828 barrels of oil per day (bopd) on a 64/64 inch choke over a nine hour period. Wellsite measurements indicated the G Sand oil to have a specific gravity of 10.7 API at 60° F. A second DST performed in the K Sand over a 6.5m perforated interval recorded initial oil flow rates of 1120 bopd on a 64/64 inch choke, consistent with previous tests at AAL-3X. However, mechanical failure of a down-hole sand screen prevented the DST from running to conclusion and a stabilised flow rate could not be achieved. Following the mechanical failure, the DST continued for five hours with oil flow rates varying from 536 to 1959 bopd. Though disappointed not to complete the full K Sand DST work program, the Joint Venture determined that sufficient data had been obtained to meet all objectives of the well and therefore a decision was made to plug and abandon the well as planned. Oil samples were recovered for further testing and wellsite measurements indicated the K Sand oil to have a specific gravity of 13.1 API at 60° F, consistent with previous tests at AAL-3X. The Joint Venture will undertake technical analysis and evaluation of this newly acquired data to be incorporated in Development Plan studies for the G Sand reservoir, which could be developed in conjunction with the already approved K Sand development. The Northwest Natuna PSC is located offshore Indonesia in the Natuna Sea and includes the Ande Ande Lumut (AAL) oil project. The AAL project comprises the K Sand reservoir (101 million barrels gross recoverable oil, net 24.3 million barrels of 2P Reserves and 1.7 million barrels 2C Contingent Resources to AWE) and the underlying G Sand reservoir. The AAL-4XST1 appraisal well targeted the G Sand reservoir, which is estimated to contain 289 million barrels gross oil in place with 36 million barrels gross recoverable oil (net 8.4 million barrels 2C Contingent Resources to AWE).

6 Jul 2016

Drilling permit for well 35/11-20 A in production licence 248 F

The Norwegian Petroleum Directorate has granted Wintershall Norge AS a drilling permit for well 35/11-20 A, cf. Section 8 of the Resource Management Regulations. Well 35/11-20 A will be drilled from the Borgland Dolphin drilling facility at position 61°13’20.29’’ north 03°26’25.57’’ east, after completing the drilling of wildcat well 16/5-6 for Tullow Oil Norge AS in production licence 776. The .... [+ read more] drilling programme for well 35/11-20 A relates to the drilling of a wildcat well in production licence 248 F. Wintershall Norge AS is the operator with an ownership interest of 40 per cent. The other licensees are Origo Exploration Norway AS (20 per cent) and Petoro AS (40 per cent). The area in this licence consists of a part of block 35/11. The well will be drilled about 100 kilometres southwest of Florø and about 20 kilometres northwest of the Fram field. Production licence 248 F was carved out of production licence 248 on 10 December 2015. Production licence 248 was awarded on 4 June 1999 (North Sea Awards 1999). This is the second well to be drilled within the licence area. The permit is contingent upon the operator securing all other permits and consents required by other authorities before commencing drilling activities.

6 Jul 2016

Lancaster 205/21a-7 Well Spud

Hurricane Energy plc, the UK-based oil and gas company focused on hydrocarbon resources in naturally fractured basement reservoirs, announces that the 205/21a-7 well on the Lancaster field, West of Shetland, was spudded at approximately 01.35 hrs on 6 July 2016, using the Transocean Spitsbergen drilling rig. The well is located on licence P1368 Central in which Hurricane has a 100% interest. .... [+ read more] The 205/21a-7 Pilot Well (the "Pilot Well") is the first in a two-well programme designed to refine the Lancaster resource range, provide a second future production well and provide new information to help optimally plan the Lancaster field development.

1 Jul 2016

Outtrim East-1 well update

Carnarvon Petroleum Limited (“Carnarvon”) (ASX:CVN) provides the following update on drilling operations as advised by the operator of the Outtrim East-1 well, Quadrant Energy. The well has reached the 12-1/4” hole section TD at a depth of 1,011m. Carnarvon notes that the first casing string was set shallower than expected due to drilling challenges in the shallow-hole section of the well .... [+ read more] around 400m, which had resulted in a delay of approximately 10 days. The well has successfully drilled through this challenging section. The well is currently rigging up to run the 9-5/8” casing liner at section TD of 1,011m. After the 9-5/8” casing liner has been cemented, drilling will continue to the expected oil zone where 90m of conventional coring will take place. After obtaining the core, the final section of the well will be drilled to a Total Depth (TD) of 1,440m. The expected cost to Carnarvon for the well is expected to be approximately $10.5m. The Outtrim East-1 well is located within the WA-155-P(1) exploration permit in the North West Shelf of Australia.

30 Jun 2016

ExxonMobil Says Second Well Offshore Guyana Confirms Significant Oil Discovery

Exxon Mobil Corporation (NYSE:XOM) today said that drilling results from the Liza-2 well, the second exploration well in the Stabroek block offshore Guyana, confirm a world-class discovery with a recoverable resource of between 800 million and 1.4 billion oil-equivalent barrels. “We are excited by the results of a production test of the Liza-2 well, which confirms the presence of high-quality .... [+ read more] oil from the same high-porosity sandstone reservoirs that we saw in the Liza-1 well completed in 2015,” said Steve Greenlee, president of Exxon Mobil Exploration Company. “We, along with our co-venturers, look forward to continuing a strong partnership with the government of Guyana to further evaluate the commercial potential for this exciting prospect.” The Liza wells are located in the Stabroek block approximately 120 miles (193 kilometers) offshore Guyana. Data from the successful Liza-2 well test is being assessed. The Liza-2 well was drilled by ExxonMobil affiliate Esso Exploration and Production Guyana Ltd., approximately 2 miles (3.3 km) from the Liza-1 well. The Liza-2 well encountered more than 190 feet (58 meters) of oil-bearing sandstone reservoirs in Upper Cretaceous formations. The well was drilled to 17,963 feet (5,475 meters) in 5,551 feet (1,692 meters) of water. “This exploration success demonstrates the strength of our long-term investment approach, as well as our technology leadership in ultra, deepwater environments,” said Greenlee. The Stabroek block is 6.6 million acres (26,800 square kilometers). Esso Exploration and Production Guyana Limited is operator and holds 45 percent interest in the Stabroek block. Hess Guyana Exploration Ltd. holds 30 percent interest and CNOOC Nexen Petroleum Guyana Limited holds 25 percent interest.

30 Jun 2016

http://www.tapoil.com.au/irm/PDF/2336/WA320PCommitmentWellDriftwood1

Tap Oil Limited (ASX:TAP) provides the following update on the WA-320-P permit in which it holds a 9.778% participating interest. The WA-320-P permit is located in the Carnarvon Basin, offshore Western Australia. As previously announced in the March 2016 quarterly (ASX release 30 April 2016) a commitment well is due in WA-320-P by the fourth quarter 2016. After extensive technical evaluation .... [+ read more] and engagement with the regulator, Quadrant Energy (formerly Apache), Operator of the WA-320-P permit, has recommended the Driftwood-1 well as the year 3 commitment well in WA-320-P, replacing the previously proposed Palmerston-1 well. The Driftwood-1 commitment well has an expected total well cost of A$15.47 million (gross), substantially lower than the estimated cost for Palmerston-1 of A$98.2 million. Tap has a 5% carry on the commitment well in WA-320-P of up to US$3.5 million (up to a total well cost of US$70 million) from JX Nippon Oil and Gas Exploration (Australia) Pty Ltd. The Driftwood-1 commitment well is located in WA-320-P in the Barrow sub-basin of the Northern Carnarvon Basin, offshore Western Australia, approximately 1km north of the Rosily-1A exploration well which had minor oil shows. Quadrant Energy has advised that the Noble Tom Prosser jackup drilling rig is expected to commence drilling the Driftwood-1 commitment well on 1 August 2016. The well objective is to test the Early Cretaceous sandstones of the Mardie Greensand Member, Birdrong Member and Zeepaard Formation in a low-relief, northeast-southwest trending four-way dip closure. A further update will be provided when drilling commences.

30 Jun 2016

Skipper Appraisal Well Update

Independent Oil and Gas plc ("IOG" or the “Company”), the development and production focused Oil and Gas Company, is pleased to announce that all resolutions were duly passed at the Company's Annual General Meeting held yesterday in London. The Company is also pleased to announce that it expects to take Transocean’s Sedco 704 semi-submersible drilling rig on contract and commence .... [+ read more] the drilling of the appraisal well on the Skipper oil discovery in the second half of July 2016. Skipper lies in Block 9/21a in licence P1609 in the Northern North Sea and IOG is the 100% owner and operator of the licence. The well is expected to take approximately 22 days to drill. The vertical well will be drilled to 5,600ft with the primary objective of retrieving good quality reservoir condition oil samples in order to optimise the Skipper field development plan. The well will also drill two mapped reservoir structures beneath the Skipper oil field in the Lower Dornoch and Maureen formations. The directors of the Company believe an approved field development plan on Skipper would convert the Board’s estimated 34.1 MMBbls of contingent resources, based on a 25% recovery factor, into 2P reserves.

29 Jun 2016

Contract Termination

Stone Energy Corporation (NYSE: SGY) today announced the termination of an existing long term deep water rig commitment and the execution of a new interim Appalachian midstream contract. Stone and Ensco have agreed to terminate Stone's current contract with Ensco for total consideration of $20 million, approximately $5 million of which was a deposit previously provided to Ensco pursuant .... [+ read more] to the drilling services contract. Further, Stone agreed to provide Ensco the opportunity to perform certain drilling services commenced before December 31, 2019, and Stone paid Ensco a $5 million deposit to be used as a credit against future drilling activities initiated before March 31, 2017, subject to extension in certain circumstances. The ENSCO 8503 deep water rig contract was at a day rate of $341,000 and was scheduled to expire in August 2017.

28 Jun 2016

Award of Contract for Semi-Submersible Tender Assist Drilling Rig SKD Berani by JX Nippon Oil & Gas Exploration (Malaysia) Limited

SapuraKencana Drilling Tioman Sdn. Bhd. has been awarded a contract by JX Nippon Oil & Gas Exploration (Malaysia) Limited (“JX Nippon”) for the provision of Semi-submersible Tender Assist Drilling Rig, SKD Berani. The contract is for JX Nippon’s development drilling campaign offshore Malaysia which comprises of three firm wells of approximately total duration of 150 days as minimum; and two .... [+ read more] option wells if exercised. The contract is expected to commence by July 2016.

28 Jun 2016

Extension of Contract for Semi-Submersible Tender Assist Drilling Rig, SKD Jaya by BP Trinidad & Tobago LLC

SapuraKencana Drilling Jaya Ltd. has accepted an extension to its contract with BP Trinidad & Tobago LLC. (“BPTT”) for the provision of its Semi-submersible Tender Assist Drilling Rig, SKD Jaya. BPTT has extended the use of the SKD Jaya for its development drilling campaign offshore Trinidad & Tobago for an additional one well for approximately 45 days and additional work .... [+ read more] on an existing well for approximately 60 days.

27 Jun 2016

Operational Update for WilPhoenix

Reference is made to Awilco Drilling's press release of 17 June. Awilco Drilling PLC is pleased to confirm that the WilPhoenix has moored at Apache's drilling location on the Storr field and resumed operations last night, 26 June. WilPhoenix is one of Awilco Drilling's two enhanced pacesetter semi-submersibles and is equipped for drilling in water depths up to 1,200 ft. .... [+ read more]

27 Jun 2016

Consent for use of Songa Encourage

Statoil has received consent to use Songa Encourage for the drilling and completion of wells at Åsgard and Heidrun. The consent covers production drilling, completion, workover, intervention and plugging. Planned start-up at Åsgard and Heidrun is mid-July 2016 and mid-December 2016 respectively. The PSA has now granted Statoil consent to use Songa Encourage at Åsgard and Heidrun in accordance with .... [+ read more] the company's application.

27 Jun 2016

Consent for exploration drilling for Det norske oljeselskap

Det norske oljeselskap (Det norske) has received consent to drill an exploration well in block 25/10. Det norske is the operator for production licence 626 in the North Sea. The well will be drilled in a prospect named Rovarkula, with the designation 25/10-15 S. Drilling will begin in July and estimated to last 25 days, depending on whether a discovery .... [+ read more] is made. Drilling will be performed by Maersk Interceptor, which is a jack-up drilling facility, delivered by the Keppel Shipyard in Singapore in 2014. The facility is owned by Maersk AS and operated by Maersk Drilling Norge AS. Maersk Interceptor was issued with an Acknowledgement of Compliance (AoC) by the PSA in December 2014. The PSA has now granted Det norske consent for exploration drilling.

27 Jun 2016

Notice of Suspension for Bideford Dolphin

Dolphin Drilling AS, a subsidiary of Fred. Olsen Energy ASA, has received notice of suspension from Statoil for Bideford Dolphin. The rig will be suspended upon completion of current well, estimated to end of June 2016. The work is expected to resume beginning of October 2016. The rig will receive a suspension rate equal to 80% of operating rate during the .... [+ read more] suspension period.

22 Jun 2016

CNSOPB permits resumption of drilling with conditions

The Canada-Nova Scotia Offshore Petroleum Board (CNSOPB) today permitted Shell Canada to resume drilling with restrictions at its Cheshire L-97 exploration well. Drilling was halted on March 5th after an operations incident on the Stena IceMAX drillship. After securing the exploration well with two barriers and successfully disconnecting to ride out heavy weather, the riser was accidentally dropped to the .... [+ read more] seafloor. No one was injured and no well fluids or synthetic oil-based drilling fluids were spilled to the environment. The CNSOPB review confirmed that the crew of the Stena IceMAX appropriately prepared for heavy weather in the days leading up to the incident on March 5th by suspending drilling, installing two barriers to secure the well (a downhole plug and the closing of the Blowout Preventer, BOP), and displacing drilling fluids in the riser to sea water. When vessel motion exceeded the operational limits, the decision was made to disconnect and ride out the weather with the riser attached to the vessel through the tensioner riser system, a standard procedure. To maximize the distance between the bottom of the riser and the BOP so as to protect the integrity of the well, the tensioner system holding the riser was fully retracted. The key factors in the cause of the incident were the heave of the vessel andthe inability of the riser tensioner system to compensate for the difference in the movement between the riser and the vessel with the tensioner system in a fully retracted position and with the Riser Anti-Recoil System (RARS) inactive. For the past three months the CNSOPB has thoroughly reviewed the incident and investigation report. It engaged independent, outside, world-class expertise in deep-water drilling to provide additional oversight. Aberdeen Drilling Management (ADM) worked with the CNSOPB in the review of the incident, the work procedures, the investigation report and an assurance plan that CNSOPB required from Shell Canada, to determine whether drilling can be safely resumed, and, if so, under what conditions. “This has been a rigorous and exhaustive review of the incident,” says CNSOPB CEO Stuart Pinks. “We are satisfied that the cause of the incident has been properly determined and that appropriate corrective actions have been taken so that drilling may resume safely. As an additional safeguard, the CNSOPB has introduced a condition further tightening operating limits under which drilling may occur.” Until such time as the CNSOPB completes further reviews, Shell Canada is required to lower its well disconnect criteria on the Stena IceMax based on vessel heave of five metres. The previous criteria was eight metres. Before permitting a return to drilling the CNSOPB sought and received assurance on a number of matters arising from the review of the incident and the investigation report. These included: Equipment – That all repaired and replacement equipment is certified, installed, commissioned, tested and compliant. Procedures – That procedures and operational criteria are reviewed and amended, where applicable, with specific focus on updated disconnect procedures and the use of weather forecasting. Training and competency – That people are trained and fully aware of changes to procedures, their roles and responsibilities, and are specifically aware of weather related disconnect criteria. In addition, disconnect drills and simulations are conducted to ensure that personnel in positions critical to the disconnect process are fully conversant with revised procedures. Risk Management – That a review of the incident investigation findings and learnings related to equipment, work procedures, and personnel competency be conducted to ensure risks are ALARP (as low as reasonably practicable). Pinks says the CNSOPB continues to review the incident, including the investigation report, to determine if future regulatory actions or changes are required. No decisions have yet been made with respect to the riser that remains on the seafloor.

21 Jun 2016

Drilling permit for wellbore 31/7-1 A in production licence 740

The Norwegian Petroleum Directorate has granted Faroe Petroleum Norge AS a drilling permit for well 31/7-1 A, cf. Section 8 of the Resource Management Regulations. Well 31/7-1 A will be drilled from the Transocean Arctic drilling facility at position 60°25'31.55"N and 3°1'28.23"E in production licence 740. The drilling programme for well 31/7-1 A relates to the drilling of an appraisal .... [+ read more] well. Faroe Petroleum Norge AS is the operator with an ownership interest of 50 per cent and Core Energy AS is a licensee with 50 per cent. The area in this licence consists of parts of blocks 31/7 and 30/9. Production licence 740 was awarded in APA 2013, 7 February 2014. This is the first well to be drilled in the licence. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

21 Jun 2016

Songa Delta suspended

Statoil will suspend the Songa Delta contract after the current well, Slemmestad, in the North Sea. From end June, 2016, the rig will go on 75% suspension rate (USD 277.000 per day). The expected resumption of the work with Statoil is indicated to be mid August 2016. The overall financial impact is expected to be limited, due to anticipated lower .... [+ read more] operating expenses in the warm-stacking period.

17 Jun 2016

Drilling permit for well 25/10-15 S in production licence 626

The Norwegian Petroleum Directorate has granted Det norske oljeselskap ASA a drilling permit for well 25/10-15 S, cf. Section 8 of the Resource Management Regulations. Well 25/10-15 S will be drilled from the Maersk Interceptor drilling facility at position 59°05’14.49’’ north 02°14’13.78’’ east. The drilling programme for well 25/10-15 S relates to the drilling of a wildcat well in production .... [+ read more] licence 626, where Det norske oljeselskap ASA is the operator with an ownership interest of 50 per cent. The other licensees are Tullow Oil Norge AS with 30 per cent, MOL Norge AS with 10 per cent and Fortis Petroleum Norway AS with 10 per cent. The area in this licence consists of part of block 25/10. The well will be drilled in the northeastern part of the licence, which is located in the central North Sea. Production licence 626 was awarded on 3 February 2012 (APA 2011). This is the first exploration well to be drilled in the licence, but the third well within the area in which the licence is located. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

17 Jun 2016

Operational Update for WilPhoenix

Reference is made to Awilco Drilling's press release of 26 April 2016 and the Q1 2016 presentation given on 11 May 2016. Awilco Drilling PLC and Apache North Sea Ltd. have agreed that WilPhoenix should leave the yard in Hartlepool around 22 June 2016 and resume operations at Apache's first drilling location around 26th June. A further update will be released .... [+ read more] once drilling operations have been resumed. WilPhoenix is one of Awilco Drilling's two enhanced pacesetter semi-submersibles and is equipped for drilling in water depths up to 1,200 ft.

16 Jun 2016

Oil and Gas Discovery at the Brasse Exploration Well

Faroe Petroleum, the independent oil and gas company focusing principally on exploration, appraisal, development and production opportunities in Norway and the UK, is pleased to announce an oil and gas discovery in the Faroe-operated Brasse exploration well in licence PL740 in the Norwegian North Sea (Faroe 50%). The Brasse well (31/7-1) has been drilled to a total depth of 2,780 .... [+ read more] metres. The well encountered approximately 18 metres of gross gas-bearing and approximately 21 metres of gross oil-bearing Jurassic reservoir which is believed to be analogous to the effective reservoir at the Brage producing oil field (Faroe 14.3%), located approximately 13 kilometres to the north of Brasse. Preliminary results based on extensive coring, wireline logs and pressure data show that the well has encountered oil and gas in reservoir sandstones of good quality. The presence of oil and gas has been confirmed subsequently by fluid sampling. The partnership has now decided to drill a sidetrack to help confirm both the reservoir distribution and hydrocarbon contacts. A further announcement will be made at the completion of drilling activities. The co-venturer in the PL740 licence is Point Resources AS (50%).

15 Jun 2016

AAL G Sand appraisal well drilling update

AWE Limited (ASX: AWE) has been advised by the Operator of the AAL-4X appraisal well, Santos Limited, that due to a mechanical obstruction in the well bore the proposed Drill Stem Tests (DST) in the K-sand and G-sand reservoirs cannot be completed in the current hole. The AAL joint venture is now planning to commence sidetrack operations to allow completion of .... [+ read more] the project scope and complete the planned DSTs. Prior to the obstruction, the well had successfully achieved all other objectives of the AAL-4X well, having intersected oil-bearing sands in both the primary G Sand and secondary K-sand objectives. The evaluation programme has successfully acquired all planned wireline logs, pressure data and oil samples from both reservoirs and also recovered approximately 63m of full core across the two reservoirs. The data acquired to date has provided significant new information to further the development planning of the K-sand reservoir and to assist with the development potential of the Gsand reservoir. The AAL-4X well was drilled to a maximum total depth of 1,246m TVDSS and was forecast to take approximately 48 days to complete. The well is being drilled in water depth of approximately 72m using the Raniworo jack-up drilling rig. The AAL-4X well is still expected to be completed within the Operator's budget, as the well has been drilled in a shorter timeframe than planned. The Northwest Natuna PSC is located offshore Indonesia in the Natuna Sea and includes the Ande Ande Lumut (AAL) oil project. The AAL project comprises the K Sand reservoir (101 million barrels gross recoverable oil, net 24.3 million barrels of 2P Reserves to AWE) and the underlying G Sand reservoir. The AAL-4X appraisal well is targeting the G Sand reservoir, which is estimated to contain 289 million barrels gross oil in place with 36 million barrels gross recoverable oil (net 10 million barrels 2C Resources to AWE). Appraisal of the G Sand will facilitate the preparation of Plan of Development for this resource, which could be developed in conjunction with the already approved K Sand development.

14 Jun 2016

PDO for Oseberg Vestflanken 2 sanctioned

The Ministry of Petroleum and Energy has sanctioned the Plan for Development and Operation (PDO) of Oseberg Vestflanken 2. Reserves projected at 110 million barrels of oil equivalent the investments are estimated at NOK 8.2 billion (2015). The Oseberg Vestflanken 2 development consists of an unmanned wellhead platform with ten well slots. In addition two existing subsea wells will be reused. .... [+ read more] All wells will be remote-controlled from Oseberg field centre. “Oseberg Vestflanken 2 is a pioneer project of great strategic importance,” says Torger Rød, Statoil’s senior vice president for project management. The project is a pilot that other operators, public authorities and the rest of Statoil’s project portfolio are already learning from. The concept is new in Norway, but has been thoroughly tested on the Danish and Dutch continental shelves. “This new concept has been required to meet the high safety standards established for installations on the Norwegian continental shelf,” Rød says. Aiming to cut investment costs throughout the engineering phase Statoil has reduced the break-even price of the project by about 30 percent thanks to reduced CAPEX and successful maturing of the resource base, thus increasing volumes. This makes the project resilient, even in a low oil price environment. The wells at Oseberg Vestflanken 2 will be drilled by the new category J rig Askepott, which is currently under construction. It is owned by the Oseberg licence. “It is gratifying that the strategies established for the procurement of Oseberg’s licence rig is now being realised through a profitable project, optimally utilising the existing infrastructure,” says Gunnar Nakken, Statoil’s senior vice president, Operations West. Helping extend the life of the Oseberg field the project is an important contribution to Statoil’s ambition of sustaining production on the NCS at the current level to 2030, and beyond. Oseberg Vestflanken 2 is the first of three planned phases for developing the remaining reserves in the Oseberg area. “Joint optimism among the Oseberg partners about the future of the Oseberg area is at the bottom of this,” Nakken concludes.

13 Jun 2016

Drilling permit for well 7222/1-1 in production licence 226

The Norwegian Petroleum Directorate has granted Eni Norge AS a drilling permit for well 7222/1-1, cf. Section 8 of the Resource Management Regulations. Well 7222/1-1 will be drilled from the Scarabeo 8 drilling facility in position 72°56' 45.94 north and 22°19' 26.18 east in production licence 226. The drilling programme for well 7222/1-1 relates to the drilling of a wildcat .... [+ read more] well in production licence 226. Eni Norge AS is the operator with an ownership interest of 60 per cent. The other licensees are DEA Norge AS with 20 per cent and Edison Norge AS with 20 per cent. The area in this licence consists of part of block 7220/1. The well will be drilled about 250 km north of Hammerfest. Production licence 226 was awarded on 30 May 1997 in the Barents Sea project. This is the first well to be drilled within the licence area. The permit is contingent on the operator securing all other permits and consents required by other authorities before the drilling activity commences.

10 Jun 2016

Delivery Delay for Perisai Pacific 102

Reference is made to our announcements of 5 October 2015 and 28 February 2013 on the deferment of delivery date and the construction of the Perisai Pacific 102, respectively. We wish to inform that we have agreed with PPL Shipyard Pte Ltd (“PPL”) to further defer the delivery date of Perisai Pacific 102 to 31 October 2016 (“Further Deferment"). The Company .... [+ read more] and PPL had earlier agreed to revise the original delivery date for the Perisai Pacific 102 to 31 March 2016. The delivery date is now revised to a date no later than 31 October 2016. The parties have further agreed that the Company shall bear no more cost for the Perisai Pacific 102 from 1 April 2016. Additionally, the parties also agreed to take the opportunity to seek and evaluate any options that may arise during this period of Further Deferment. Apart from the above, all other contractual provisions remain the same.

9 Jun 2016

Divestment of Ben Rinnes Jack-Up Drilling Unit

Leading global drilling and engineering contractor, KCA Deutag, today announces that it has sold its jack-up drilling unit, the Ben Rinnes, to an integrated energy and services company for an undisclosed sum. Built in Clydebank, Scotland in 1973 and acquired by KCA Deutag in 2005, the Ben Rinnes was under contract offshore Angola until February of this year. .... [+ read more] The ABS Classed Marathon Le Tourneau MLT 53-S enhanced rig has been stacked in Gabon since then. Norrie McKay, KCA Deutag CEO said: “Whilst the sale of the Ben Rinnes is an important milestone for KCA Deutag as it is our last asset in our mobile offshore drilling fleet, we continue to maintain the competence and experience required to support offshore drilling unit operations. This expertise is currently supporting the construction and start-up of two Category J jack-up rigs which will commence operations on the Norwegian Continental Shelf next year.”

9 Jun 2016

Minor gas/condensate discovery southwest of the Oseberg South field in the North Sea - 30/11-13

Statoil Petroleum AS, operator of production licence 272, has completed the drilling of wildcat well 30/11-13. The well proved gas/condensate. The well was drilled eight kilometres southeast of the 30/11-8 S (Krafla) discovery and about 27 kilometres south of the Oseberg South facility in the North Sea. The primary exploration target for the well was to prove petroleum .... [+ read more] in Middle Jurassic reservoir rocks (the Tarbert formation). The secondary exploration target was to prove petroleum in Middle Jurassic reservoir rocks (the Ness formation). The well encountered gas columns at two levels in the top part of the Tarbert formation, a total of 5 and 31 metres, respectively, of which 4 and 22 metres had good to moderate reservoir properties. The secondary exploration target in the Ness formation is aquiferous. The preliminary estimation of the size of the discovery is between one and three million standard cubic metres (Sm3) of recoverable oil equivalents. The discovery will be included in the evaluation of a new field development along with previous discoveries in the area. Data has been collected and samples were taken from the well. Well 30/11-13 was drilled to a vertical depth of 3313 metres below the sea surface and was terminated in the Ness formation. The well is the fourth exploration well in production licence 272. The licence was awarded in the North Sea Awards in 2001. Water depth is 106 metres. The well will be permanently plugged and abandoned. Well 30/11-13 was drilled by the Songa Delta drilling facility, which will continue the drilling campaign by drilling wildcat well 30/11-14 in the same production licence, where Statoil Petroleum AS is the operator.

9 Jun 2016

Drilling permit for well 7220/11-3 AR in production licence 609

The Norwegian Petroleum Directorate has granted Lundin Norway AS a drilling permit for well 7220/11-3 AR, cf. Section 8 of the Resource Management Regulations. Well 7220/11-3 AR will be drilled from the Leiv Eiriksson drilling facility at position 72°56'45,94" north and 22°19'26,18" east in production licence 609. The drilling programme for well 7220/11-3 AR relates to the deepening of appraisal .... [+ read more] well 7220/11-3 A, which was temporarily plugged and abandoned in 2015 in production licence 609. Lundin Norway AS is the operator with an ownership interest of 40 per cent. The other licensees are Idemitsu Petroleum Norge AS and DEA Norge AS, each with 30 per cent. The area in this licence consists of blocks/parts of blocks 7220/6, 7220/9, 7220/11, 7220/12 and 7221/4. The well will be drilled about four kilometres south of the 7220/11-1 discovery well. Production licence 609 was awarded on 13 May 2011 in the 21st licensing round on the Norwegian shelf. The permit is contingent on the operator securing all other permits and consents required by other authorities prior to commencing the drilling activities.

9 Jun 2016

Saipem awarded new drilling contracts worth approximately €150 million

Saipem has been awarded by Eni Portugal B.V. a contract for the utilization of the Saipem 12000, which will operate offshore Portugal. The work will be performed during the third quarter of 2016. Saipem 12000 is a sixth generation ultra-deepwater drilling ship capable of operating in water depths of over 3,000 metres. .... [+ read more]

7 Jun 2016

Drilling permit for well 36/7-4 in production licence 636

The Norwegian Petroleum Directorate has granted ENGIE E&P Norge AS a drilling permit for well 36/7-4, cf. Section 8 of the Resource Management Regulations. Well 36/7-4 will be drilled from the Transocean Arctic drilling facility at position 61°24’59.72’’ north, 04°04’08.06’’ east after the facility concludes the drilling of wildcat well 31/7-1 A for Faroe Petroleum Norge AS in production licence 740. .... [+ read more] The drilling programme for well 36/7-4 relates to the drilling of a wildcat well in production licence 636. ENGIE E&P Norge AS is the operator with an ownership interest of 30 per cent. The other licensees are Idemitsu Petroleum Norge AS (30 per cent), Wellesley Petroleum AS (20 per cent) and Tullow Oil Norge AS (20 per cent). The area in this licence consists of a part of block 36/7. The well will be drilled approx. 55 km southwest of Florø and about 10 km northwest of the Gjøa field. Production licence 636 was awarded on 3 February 2012 (APA 2011). This is the first well to be drilled within the licence area. The permit is contingent on the operator securing all permits and consents required by other authorities prior to commencing the drilling activity.

7 Jun 2016

North Atlantic Drilling Ltd. announces amendment to agreement with Jurong

North Atlantic Drilling Ltd. ("NADL" or "the Company") refers to the press release on December 3, 2015 which announced a standstill agreement to defer delivery of the semi-submersible West Rigel ("the Unit"). Today the Company announces an amendment has been agreed with Jurong Shipyard Pte Ltd ("Jurong"), which extends the delivery deferral period by a further three months to September .... [+ read more] 2, 2016. The extension allows the parties to continue to explore commercial opportunities for the Unit. As previously agreed, in the event no employment is secured for the Unit and no alternative transaction is completed, the Company and Jurong will form a Joint Asset Holding Company for joint ownership of the Unit, to be owned 23% by the Company and 77% by Jurong.

7 Jun 2016

Skipper Appraisal Well rescheduled for July 2016

Independent Oil and Gas plc ("IOG" or the “Company”), (AIM: IOG.L), is pleased to announce that the appraisal well on the Skipper oil discovery which lies in Block 9/21a in licence P1609 in the Northern North Sea, is scheduled to be drilled in July 2016. Drilling of the Skipper appraisal well, of which IOG is 100% owner and operator, is scheduled .... [+ read more] for July 2016 and will be drilled by Transocean’s Sedco 704 semi-submersible.

7 Jun 2016

INPEX to Commence Exploratory Offshore Drilling in Japan

TOKYO, JAPAN - INPEX CORPORATION (INPEX) announced today it commenced drilling operations on an exploratory well offshore Shimane and Yamaguchi prefectures on June 5. The drilling operations are part of a project commissioned by the Agency of Natural Resources and Energy of the Ministry of Economy, Trade and Industry (METI) of Japan for the agency’s “Heisei 26~28 Domestic Offshore Drilling Program .... [+ read more] in Japan” as announced on July 30, 2015. The drilling operations are being conducted at a location approximately 130km northwest of Shimane Prefecture and approximately 140km north of Yamaguchi Prefecture. Going forward, INPEX plans to determine the presence of hydrocarbon deposits in the area by conducting a detailed analysis and evaluation of data obtained through the exploratory drilling. INPEX will prioritize safety throughout the execution of the project, keeping local communities fully informed and calling on their cooperation.

7 Jun 2016

HAKURYU-10 receives Total E&P 2015 Best Rig Performance Award

Japan Drilling Company (JDC) jack-up rig HAKURYU-10 received French Oil Major Total E&P 2015 Best Rig Performance Award, outperforming 45 other rigs in Total E&P worldwide operations. The award ceremony took place on 7 June aboard HAKURYU-10, offshore Balikpapan, Indonesia. DC President Yuichiro Ichikawa expressed his pride in the HAKURYU-10 achievement to Total E&P representatives. He expressed his sincere gratitude for .... [+ read more] the tremendous support and appreciation for the superior communication between the two parties that resulted in the safe and smooth operations from the July 2012 commencement of the campaign. Mr. Ichikawa said that he intends to implement specific efficiency practices of HAKURYU-10 to further improve operational performance of JDC Group rigs. In his closing remarks Mr. Ichikawa said he looks forward to working together with Total E&P at the nearest opportunity.

2 Jun 2016

Rosneft commences drilling in the Sea of Okhotsk

JV of Rosneft and Statoil ASA started drilling the exploration well in the Sea of Okhotsk. The signal to begin drilling was given by the Rosneft Chairman of the Management Board Igor Sechin during the work at the rig Nanhai-9. "Implementation of the offshore projects in upstream is one of the Company’s most important strategic goals, a contribution to .... [+ read more] the whole oil and gas industry. Rosneft is the country’s only company that continues the work on new projects offshore in accordance with its license obligations despite the complicated external environment. We are pleased to commence the key stage of project within the scope of the long-term cooperation with our partner – Statoil – the drilling of exploration wells in the Sea of Okhotsk" - Igor Sechin said. Well Ulberikanskaya-1 will be drilled at the prospect of the same name in Lisiansky license area one year ahead of the license obligations. The distance from the port of Magadan to the well is about 420 km. The second well of Rosneft and Statoil project will be also drilled during the 2016 season within Magadan-1 section in the Sea of Okhotsk. Semi-submersible rig Nanhai-9 was delivered by China Oilfield Services Limited (COSL) which signed a contract for drilling with the joint venture of Rosneft and Statoil in September 2015. The rig was transported through the South China Sea, the East China Sea, the Sea of Japan and the Sea of Okhotsk; to reach the point of drilling, the rig traveled a long way of more than 4600 nautical miles. Nanhai-9 was specially modified for the drilling project in the Sea of Okhotsk: in particular, a comprehensive preparation of the rig was implemented to enable its operation at low ambient temperatures, wind protection was installed on the perimeter of the drilling site, a range of services were held to ensure environmentally safe operations. The Sea of Okhotsk lies south of the Arctic zone boundary, the sea depth in both drilling sites is less than 150 m.

2 Jun 2016

Consent for exploration drilling for Tullow Oil Norge AS

Tullow Oil Norge AS (TONAS) has received consent to drill an exploration well in block 16/5. TONAS is the operator for production licence 776 in the North Sea. The well will be drilled in a prospect named Rome, with the designation 16/5-6. It is located around 37 kilometres southeast of the Edvard Grieg field. Drilling is scheduled to begin in .... [+ read more] June at the earliest and estimated to last 30 days, depending on whether a discovery is made. Drilling will be performed using Borgland Dolphin, which is a semi-submersible mobile drilling facility of the Aker H-3 type. The facility is owned by Fred. Olsen Energy ASA and operated by Dolphin Drilling AS. It was built as a flotel in 1977 and refitted/upgraded into a drilling facility in 1999. Borgland Dolphin received Acknowledgement of Compliance (AoC) from the PSA in September 2004. The PSA has now granted TONAS consent for exploration drilling.

1 Jun 2016

Pemex issues certificate of acceptance for Impetus

On May 29, 2016 Perforadora Oro Negro, S. de R.L. de C.V. (“Oro Negro”) completed the checklist for its Impetus rig and, consequently, Pemex Perforación y Servicios, EPS issued the certificate of acceptance for said rig to begin operations. .... [+ read more]

31 May 2016

Sembcorp Marine delivers jack-up rig Maersk Highlander

Sembcorp Marine, a global leader in offshore and marine engineering solutions, has delivered the high-specification jack-up rig Maersk Highlander (formerly known as Hercules Highlander) to Maersk Highlander UK Ltd. The Maersk Highlander is constructed based on the Friede & Goldman JU 2000E design and is fully compliant with UK HSE standards. It is well suited for harsh-environment operations and will be .... [+ read more] deployed in the Culzean Field Development, located in the UK sector of the North Sea. As a heavy-duty offshore drilling asset, the Maersk Highlander can operate in water depths of up to 400 feet and drill to 30,000 feet deep. Its notable capabilities include a 2-million-pound drilling capacity, 6,000 barrels of mud capacity, 28,000-kip preload capacity for the legs, and an accommodation facility that houses up to 150 workers. The rig’s construction started in September 2014 and was completed on schedule with an excellent safety record of zero near-misses and reportable cases. This is testament to the high standard of workplace safety and health upheld by all personnel involved in the project, including Sembcorp Marine’s vendor partners. Sembcorp Marine President and CEO Wong Weng Sun said: “Other than an outstanding safety record, the successful Maersk Highlander project reinforces Sembcorp Marine’s solid reputation as an efficient and reliable rig builder, supported by strong production capabilities as well as highly competent project management and technical personnel. As a technology-driven company, we are constantly seeking ways to innovate and offer the most effective solutions to our customers.”

30 May 2016

Drilling permit for wells 30/11-14, 30/11-14 A and 30/11-14 B in production licence 035

The Norwegian Petroleum Directorate (NPD) has granted Statoil Petroleum AS a drilling permit for wells 30/11-14, 30/11-14 A and 30/11-14 B, cf. Section 8 of the Resource Management Regulations. The three wells will be drilled from the Songa Delta drilling facility at position 60°11’29.9’’ north and 02°35’11.4’’ east in production licence 035. The drilling programme relates to the drilling of .... [+ read more] two wildcat wells (30/11-14 and 30/11-14 B) and one appraisal well (30/11-14 A) which will be drilled if a discovery is made. Statoil is the operator with an ownership interest of 50 per cent. Det norske oljeselskap ASA is the licensee with 50 per cent. The area in this licence consists of a part of block 30/11. Production licence 035 was awarded in licensing round 2-A on 14 November 1969. These are the 12th, 13th, and possibly the 14th exploration wells to be drilled within the licence area. The permit is contingent on the operator securing all other permits and consents required by other authorities before the drilling activity commences.

30 May 2016

Minor oil discovery and dry appraisal well southwest of the Oseberg Sør field in the North Sea - 30/11-12 S and 30/11-12 A

Statoil Petroleum AS, operator of production licence 035, is in the process of concluding the drilling of wildcat well 30/11-12 S and appraisal well 30/11-12 A. The wells were drilled two kilometres south of the 30/11-9 A (Askja Øst) discovery, and about 35 km southwest of the Oseberg Sør facility in the North Sea. The objective of well .... [+ read more] 30/11-12 S was to prove petroleum in three sandstone layers in Middle Jurassic reservoir rocks (the Tarbert formation). The objective of well 30/11-12 A was to delineate in the event a discovery was made in 30/11-12 S. 30/11-12 S encountered a 37-metre oil column in the upper part of the Tarbert formation, of which about 30 metres had good to moderate reservoir properties. Well 30/11-12 A, which was drilled further down on the structure, encountered similar reservoir rocks, but is dry. Preliminary estimates place the size of the discovery at between 0.7 and 2.5 million standard cubic metres (Sm3) of recoverable oil equivalents. The discovery will be included in the evaluation of a new field development, along with other earlier discoveries in the area. Data has been collected and samples have been taken in both wells. Wells 30/11-12 S and 30/11-12 A were drilled to vertical and total depths of 3669 and 3671 metres, respectively, and 3609 and 4144 metres below the sea surface. 30/11-12 S was terminated in the Ness formation and 30/11-12 A was terminated in the Tarbert formation. The wells are the 12th and 13th exploration wells in production licence 035. The licence was awarded in the 2nd licensing round in 1969. Water depth is 110 metres. The wells have been permanently plugged and abandoned. Wells 30/11-12 S and 30/11-12 A were drilled by the Songa Delta drilling facility, which will continue its drilling campaign with the drilling of wildcat well 30/11-13 S in the same production licence, where Statoil Petroleum AS is the operator.

27 May 2016

Maersk Drilling acquires newbuild harsh environment jack-up rig with a five-year drilling contract

Maersk Drilling has entered into a definitive agreement to acquire the newbuild harsh environment jack-up rig, formerly named Hercules Highlander, from a subsidiary of Hercules Offshore (Nasdaq: HERO) and with immediate delivery from Jurong Shipyard Pte Ltd (Jurong) in Singapore. According to the agreement, Maersk Drilling assumes the right to take delivery of the rig and Maersk Drilling .... [+ read more] settles the final payment of approx. USD 190m with Jurong. After delivery, the rig will be mobilised to the North Sea to commence a five-year drilling contract with Maersk Oil and its partners, BP and JX Nippon, on the Culzean gas field offshore UK. The value of the five-year drilling contract is approx. USD 420m, including a mobilisation fee of USD 9m. “This agreement represents an opportunity for Maersk Drilling to acquire a newbuild harsh environment jack-up backed by a firm long-term contract. We look forward to working with Maersk Oil and its partners on the Culzean gas field,” says CEO in Maersk Drilling and member of the Executive Board in the Maersk Group, Claus V. Hemmingsen. The rig design is Friede & Goldman JU2000E, categorised as a 400ft rig, with 30,000ft drilling depth and HPHT (High Pressure High Temperature) capabilities. The rig has accommodation capacity for up to 150 personnel. The rig will enter the Maersk Drilling fleet under the name Maersk Highlander, and after the acquisition, Maersk Drilling’s rig fleet counts 23 rigs with an additional harsh environment jack-up rig under construction.

27 May 2016

Delineation of the 16/1-7 oil discovery in the North Sea – 16/1-26 S and 16/1-26 A

Det norske oljeselskap AS, operator of production licence 001 B, has concluded the drilling of appraisal wells 16/1-26 S and 16/1-26 A. The wells were drilled about 1.5 kilometres southeast of the 16/1-7 discovery well in the central part of the North Sea. The 16/1-7 (West Cable) oil discovery was proven in Middle Jurassic reservoir rocks (the Sleipner formation) in .... [+ read more] 2004 and is part of the Ivar Aasen field. The size of the discovery prior to drilling the appraisal wells was 2.1 million standard cubic metres (Sm3) of recoverable oil equivalents. The objective of appraisal wells 16/1-26 S and 16/1-26 A was to prove additional recoverable oil resources in the southern part of the 16/1-7 discovery, in Middle Jurassic reservoir rocks (the Sleipner formation) closer to the main structure on the Ivar Aasen field. The appraisal wells were drilled from a production well being drilled from the Ivar Aasen platform. 16/1-26 S encountered a gas/oil column of about 25 metres in Middle Jurassic reservoir rocks (the Hugin formation), of which 15 metres were sandstone of moderate to good reservoir quality. The oil/water contact was not encountered, but was estimated to be at approximately 2700 metres vertical depth. This is shallower than the previously estimated oil/water contact for the 16/1-7-discovery. 16/1-26 A encountered about 75 metres of sandstone in the Sleipner formation with moderate to good reservoir quality, but is dry. Preliminary estimates place the additional resources at between 0.5 and 2 million standard cubic metres (Sm3) of recoverable oil equivalents. The licensees will assess recovery of the additional resources. The results have yielded valuable information as regards final placement of the development well on the 16/1-7 discovery. None of the wells were formation-tested, but data acquisition and sampling have been carried out. Wells 16/1-26 S and 16/1-26 A were drilled to measured depths of 5309 and 4888 metres, respectively, and vertical depths of 2912 and 3044 metres below the sea surface. The wells were terminated in the Skagerrak formation in the Upper Triassic and the Sleipner formation in the Middle Jurassic, respectively. The wells have been permanently plugged and abandoned. Water depth is 113 metres. The wells were drilled using the Maersk Interceptor drilling facility, which will now continue with the pre-drilling programme on the Ivar Aasen field, which has a planned production start-up date of 1 December 2016.

26 May 2016

Sri Trang final drilling update

The Sri Trang-1 exploration well is located in the Reservation Area of the G1/48 concession in the Gulf of Thailand approximately 18 kilometres north northeast of the Manora oil development. Mubadala Petroleum is the operator of G1/48. The well was spudded at 17.30 hrs (WST) on 17 May 2016 in 40 metres of water by the Atwood Orca jackup drilling unit .... [+ read more] and was drilled to an extended final total depth of 2,814 meters measured depth. The test results confirmed the presence of oil in poor quality reservoir sand. The samples collected from three other zones confirmed the presence of water. Although the oil is not in commercial quantities, the Sri Trang-1 discovery has validated the hydrocarbon prospectivity of the Northern Kra Basin. The drilling cost of the Sri Trang-1 well will be offset against the G1/48 Reservation Area fee (~US$3.8 million) paid to the Thai Department of Mineral Fuels by the Joint Venture of the Reservation Area in the G1/48 concession. It is estimated that Tap may be required to contribute up to a further US$0.1 million above the Reservation Area refund.

25 May 2016

Consent for exploration drilling for Eni Norge

Eni Norge has received consent to drill an exploration well in block 7222 in the Barents Sea. Eni Norge is the operator for production licence 226 in the Barents Sea. The well is to be drilled in a prospect named Aurelia, with the designation 7222/1-1. Water depth at the site is 424 metres. Drilling is estimated to last for 58 .... [+ read more] days, depending on whether a discovery is made. 25.05.2016 Print Tip someone Register for news Eni Norge is the operator for production licence 226 in the Barents Sea. The well is to be drilled in a prospect named Aurelia, with the designation 7222/1-1. The geographical coordinates are: 72° 56' 45.9401" N 22° 19' 26.1847" E Water depth at the site is 424 metres. Drilling is estimated to last for 58 days, depending on whether a discovery is made. Drilling is to be performed by Scarabeo 8 which is a semi-submersible drilling facility of the Moss CS 50 MkII design. The facility is winterised and is designed for working at water depths of between 70 and 3050 metres.

23 May 2016

Small oil discovery and dry well near the Vega field in the North Sea – 35/8-6 S and 35/8-6 A

Wintershall Norge AS, operator of production licence 248, has completed the drilling of wildcat wells 35/8-6 S and 35/8-6 A. The wells were drilled about five km northwest of the Vega field in the North Sea and 150 km northwest of Bergen. The purpose of both wells was to prove petroleum in Upper Jurassic reservoir rocks (sandstone in the Heather formation). .... [+ read more] Well 35/8-6 S encountered a poorly developed reservoir in the Heather formation. The well is dry. Well 35/8-6 A encountered a three-metre oil column in the Heather formation with poor reservoir quality. Preliminary estimates concerning the size of the discovery range between 0.2 and 1 million standard cubic metres (Sm3) of recoverable oil. Extensive data collection and sampling have been undertaken. These are the sixth and seventh exploration wells in production licence 248. The licence was awarded in the North Sea Awards 1999. Wells 35/8-6 S and 35/8-6 A were drilled to a measured depth of 4043 metres and 3800 metres, respectively, below sea level and to a vertical depth of 3713 metres and 3529 metres, respectively, below sea level. Both were terminated in the Heather formation. The sea depth is 381 metres. The wells have now been permanently plugged and abandoned. Wells 35/8-6 S and 35/8-6 A were drilled by Borgland Dolphin, which is now heading for production licence 248 F in the North Sea to drill wildcat well 35/11-19 S, which is operated by Wintershall Norge AS.

23 May 2016

Seadrill Receives Notice of Contract Cancellation for the West Hercules

Seadrill Limited ("Seadrill" or the "Company") has received a notice of termination for convenience from the current operator related to the contract for the West Hercules which was originally contracted for drilling in Norway with North Atlantic Drilling Ltd.. In accordance with the contract, the Company will receive a lump sum payment of approximately $61 million, plus dayrate and reimbursement of .... [+ read more] costs associated with demobilization of the rig. The West Hercules is currently being marketed for new work.

23 May 2016

Cancellation of rig contract

Statoil has, on behalf of the Aasta Hansteen licence, decided to cancel the contract with Seadrill for the West Hercules drilling rig. On contract with Statoil since 31 January 2013, the rig has carried out an exploration campaign offshore Newfoundland in Canada for the past 18 months. According to the original plan the Aasta Hansteen licence was to take over .... [+ read more] the rig in the second quarter of 2016 for a drilling campaign to be started around 1 July 2016. In the autumn of 2015 it was decided to postpone the Aasta Hansteen field start-up one year until the last half of 2018, and consequently the field drilling programme will also be postponed. One of the reasons is that it is not preferable to complete the wells too early before production start-up. The contract for West Hercules was originally to expire on 31 January 2017.

23 May 2016

Rowan to receive $215 million payment plus potential $30 million in contingent payments

Rowan Companies plc (NYSE: RDC) today announced an agreement with its customer, Freeport-McMoRan Oil & Gas LLC (FMOG), and FMOG's parent company, Freeport-McMoRan Inc. (Freeport), in connection with a drilling contract for the drillship Rowan Relentless, which was scheduled to terminate in June 2017. The agreement provides that the drilling contract will be terminated immediately, and Freeport will pay Rowan .... [+ read more] $215 million in cash to settle outstanding receivables and early termination of the contract. Rowan may also receive additional contingent payments from Freeport of $10 million and $20 million, respectively, depending on the average price of oil over a 12-month period. In addition, Rowan expects to reduce its costs for the Rowan Relentless by efficient warm stacking of the rig. Freeport recently announced a restructuring of its oil and gas business, which is operated through FMOG. As disclosed in Freeport's public filings, FMOG has substantial debt and has been negatively impacted by the sustained downturn in oil prices. Tom Burke, President & CEO of Rowan, commented: "I am satisfied with this resolution given FMOG did not have any ongoing work for the Rowan Relentless. This accelerated payment provides additional liquidity to further strengthen our balance sheet and affords Rowan added flexibility as we review opportunities in this down market. The Rowan Relentless, our fourth high-specification ultra-deepwater drillship, had outstanding operational performance on this contract, delivering safe, reliable and efficient operations."

19 May 2016

Drilling permit for well 31/7-1 in production licence 740

The Norwegian Petroleum Directorate has granted Faroe Petroleum Norge AS a drilling permit for well 31/7-1, cf. Section 8 of the Resource Management Regulations. Well 31/07-01 will be drilled from the Transocean Arctic drilling facility at position 60°25'31.56"N and 3°1'28.26"E in production licence 740. The drilling programme for well 31/7-1 concerns drilling of a wildcat well. Faroe Petroleum Norge AS .... [+ read more] is the operator and has an ownership interest of 50 per cent, while Core Energy AS is a licensee with a 50 per cent interest. The area in this licence is part of blocks 31/7 and 30/9. Production licence 740 was awarded in APA 2013, 7 February 2014. This is the first well to be drilled in the licence. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

19 May 2016

Senegal Drilling Update: Successful SNE-4 appraisal well

The SNE-4 appraisal well offshore Senegal has been safely drilled, cored and logged ahead of schedule and under budget. Well results have successfully demonstrated the extension of the SNE oil field upper reservoir units in the eastern portion of the SNE field. The Operator, Cairn Energy PLC, has provided notice to release the Ocean Rig Athena drill ship after completion of .... [+ read more] SNE-4 operations. Evaluation of the extensive data set acquired from the highly successful SNE-2, SNE-3, BEL-1 and SNE-4 appraisal wells is continuing. The JV is evaluating development options and will determine the most effective way to further appraise this world class oil accumulation. Drilling is expected to resume in H2 2016.

18 May 2016

Drilling permit for well 30/4-3 S in production licence 040/043

The Norwegian Petroleum Directorate (NPD) has granted Total E&P Norge AS a drilling permit for well 30/4-3 S, cf. Section 8 of the Resource Management Regulations. Well 30/4-3 S will be drilled with the Mærsk Intrepid rig at position 60°30'22.44"N and 2°0'53.37"E in production licence 040/043. The drilling programme for well 30/4-3 S relates to the drilling of a wildcat .... [+ read more] well. Total E&P Norge AS is the operator with an ownership interest of 51 per cent, Petoro has 30 per cent and Statoil Petroleum AS has 19 per cent. The area in this licence consists of a part of block 30/4. Production licence PL 040 was awarded in the 3rd licensing round on 1 April 1975, and PL 043 was awarded on 31 Dec. 1975. This is the third exploration well to be drilled within the licence area. A total of 16 wells, including sidetracks, have been drilled in the Martin Linge area. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

18 May 2016

Drilling permit for well 16/5-6 – Production licence 776

The Norwegian Petroleum Directorate has granted Tullow Oil Norge AS a drilling permit for wellbore 16/5-6. Wellbore 16/5-6 will be drilled from the Borgland Dolphin drilling facility at position 58°32’40.45’’ N and 02°31’45.5” E. The drilling programme for wellbore 16/5-6 relates to the drilling of a wildcat well in production licence 776. Tullow Oil Norge AS is the operator with .... [+ read more] an ownership interest of 40 per cent. The licensees are Concedo ASA with 20%, Wintershall Norge AS with 20% and Petoro AS with a 20% ownership interest. Production licence 776 was awarded in 2015 (APA 2014). The area in this production licence is located in the central part of the North Sea, and consists of parts of blocks 16/5, 6, 8 and 9. The well will be drilled about 30 km south of the Johan Sverdrup field. This is the first well to be drilled within the production licence area. The drilling permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

16 May 2016

AAL JV spuds G Sand appraisal well

AWE Limited (ASX: AWE) advises that the Operator of the Northwest Natuna PSC, Santos Limited (ASX: STO), has confirmed that the AAL-4X appraisal well was spudded successfully at 20:00 hours (8.00pm) AEDT on 14 May 2016. As at 09:00 hours (9.00am) AEDT Monday 16 May, the well was at 200m Total Vertical Depth Sub Sea (TVDSS) in a 24 inch hole. .... [+ read more] The AAL-4X well will be drilled to a planned maximum total depth of 1,232m TVDSS and is forecast to take approximately 48 days to complete. The well is being drilled in water depth of approximately 72m using the Raniworo jack-up drilling rig. The Northwest Natuna PSC is located offshore Indonesia and includes the Ande Ande Lumut (AAL) oil project. The AAL project comprises the K Sand reservoir (101 million barrels gross recoverable oil, net 24.3 million barrels of 2P Reserves to AWE) and the underlying G Sand reservoir. The AAL-4X appraisal well is targeting the G Sand reservoir, which is estimated to contain 289 million barrels gross oil in place with 36 million barrels gross recoverable oil (net 10 million barrels 2C Resources to AWE). Appraisal of the G Sand will facilitate the preparation of Plan of Development for this resource, which could be developed in conjunction with the already approved K Sand development.

13 May 2016

Drilling permit for wellbore 35/11-19 S in production licence 248 F

The Norwegian Petroleum Directorate has granted Wintershall Norge AS a drilling permit for wellbore 35/11-19 S, cf. Section 8 of the Resource Management Regulations. Wellbore 35/11-19 S will be drilled from the Borgland Dolphin drilling facility at position 61°13’21.45’’ north 03°26’27.88’’ east after completing the drilling of wildcat well 35/8-6 A for Wintershall Norge AS in production licence 248. The .... [+ read more] drilling programme for wellbore 35/11-19 S relates to the drilling of a wildcat well in production licence 248 F. Wintershall Norge AS is the operator with an ownership interest of 40 per cent. The other licensees are Origo Exploration Norway AS (20 per cent) and Petoro AS (40 per cent). The area in this licence consists of a part of block 35/11. The well will be drilled about 100 kilometres southwest of Florø and about 20 kilometres northwest of the Fram field. Production licence 248 F was carved out of production licence 248 on 10 December 2015. Production licence 248 was awarded on 4 June 1999 (North Sea Awards 1999). This is the first well to be drilled within the licence. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

13 May 2016

SDLP - Termination of the West Capella

Seadrill Partners LLC ("the Company") has received a notice of termination from its current operator for the contract for the West Capella. In accordance with the cancellation for convenience provisions in the West Capella contract, Seadrill Partners will receive a payment of approximately $125 million in two equal installments, the first in the second quarter of 2016 and the .... [+ read more] second in the first quarter of 2017, plus other direct costs incurred as a result of the early termination. The West Capella is currently being marketed for new work and is expected to be in Tenerife during its idle period.

12 May 2016

Delivery Delay for the KS Orient Star 2

The Board of Directors (the “Board”) of KS Energy Limited (the “Company”, and together with its subsidiaries, the “Group”) refers to the announcement dated 26 May 2011, the circular to shareholders dated 16 September 2011 in relation to the New Build Contracts (as defined therein) with COSCO Nantong Shipyard Co., Ltd. (“COSCO Shipyard”), and the announcement dated 10 July 2015. The .... [+ read more] Board wishes to announce that the KS Drilling Pte Ltd (“KS Drilling”) has entered into a further amendment agreement dated 5 May 2016 (the “Further Amendment Agreement”) with COSCO Shipyard in relation to the New Build Contract (the “Contract”) for the New Rig with builder’s hull number N408 (the “Rig”). In the spirit of partnership between KS Drilling and COSCO Shipyard, and in light of the currently unfavourable oil and gas market climate, and pursuant to the Further Amendment Agreement, KS Drilling and COSCO Shipyard have agreed to extend the time for KS Drilling to take delivery of the Rig from 30 April 2016 until 31 December 2017, on mutually agreed terms and conditions. The Further Amendment Agreement is not expected to have any material impact on the net tangible assets and earnings per share of the Company and the Group for the current financial year ending 31 December 2016. None of the Directors or substantial shareholders of the Company has any direct or indirect interest in the above transactions, save for their respective interest, through their shareholdings and/or directorships, as the case may be, in the Company.

11 May 2016

Consent for exploration drilling for Faroe Petroleum

Faroe Petroleum has received consent to drill an exploration well in block 37/1. Faroe Petroleum Norge AS (Faroe Petroleum) is the operator for production licence 740 in the North Sea. The exploration well will be the first to be drilled in this production licence. It will be drilled in a prospect named Brasse, with the designation 31/7-1. The location is 16 .... [+ read more] km south-east of Oseberg A and approx. 93 km west of Sotra in Hordaland. Water depth at the site is 188 metres. The drilling will start in the second half of May at the earliest, with an estimated duration of up to 57 days. The drilling will be performed using Transocean Arctic, which is a semi-submersible mobile drilling facility operated by Transocean Offshore (North Sea) Ltd NUF. It was built by Mitsubishi Heavy Industries in Japan in 1987, and substantially upgraded in 2004. Transocean Arctic was issued with an Acknowledgement of Compliance (AoC) by the PSA in July 2004. The PSA has granted Faroe Petroleum consent for the exploration drilling.

11 May 2016

Consent for exploration drilling for Wintershall

Wintershall has received consent to drill an exploration well in block 35/11. Wintershall Norge AS (Wintershall) is the operator for production licence 248 in the North Sea. The well will be drilled in a prospect named Orion, with the designation 35/11-19S. The location is around 98 km west-south-west of Florø. Water depth at the site is 379 metres. The .... [+ read more] drilling will start in mid-May at the earliest, with an estimated duration of between 47 and 134 days. The duration will depend on whether a discovery is made, which in turn will entail drilling sidetrack wells. The well will be drilled by Borgland Dolphin, which is a semi-submersible mobile drilling facility of the Aker H-3 type. The facility is owned by Fred. Olsen Energy ASA and operated by Dolphin Drilling AS. It was built as a flotel in 1977 and refitted/upgraded into a drilling facility in 1999. Borgland Dolphin was issued with an Acknowledgement of Compliance (AOC) by the PSA in September 2004. The PSA has granted Wintershall consent for the exploration drilling.

11 May 2016

Consent for exploration drilling for Faroe Petroleum

Faroe Petroleum has received consent to drill an exploration well in block 37/1. Faroe Petroleum Norge AS (Faroe Petroleum) is the operator for production licence 740 in the North Sea. The exploration well will be the first to be drilled in this production licence. It will be drilled in a prospect named Brasse, with the designation 31/7-1. The location is 16 .... [+ read more] km south-east of Oseberg A and approx. 93 km west of Sotra in Hordaland. Water depth at the site is 188 metres. The drilling will start in the second half of May at the earliest, with an estimated duration of up to 57 days. The drilling will be performed using Transocean Arctic, which is a semi-submersible mobile drilling facility operated by Transocean Offshore (North Sea) Ltd NUF. It was built by Mitsubishi Heavy Industries in Japan in 1987, and substantially upgraded in 2004. Transocean Arctic was issued with an Acknowledgement of Compliance (AoC) by the PSA in July 2004. The PSA has granted Faroe Petroleum consent for the exploration drilling.

10 May 2016

Noble Corporation plc Announces Agreement with Freeport-McMoRan

Noble Corporation plc (NYSE: NE) today announced an agreement with its client, Freeport-McMoRan Oil & Gas LLC (FMOG), and FMOG’s parent company, Freeport-McMoRan Inc. (Freeport), in connection with the drilling contracts for the drillships Noble Sam Croft and Noble Tom Madden, which were scheduled to terminate in July and November 2017, respectively. Pursuant to the agreement, the contracts will be .... [+ read more] terminated, with operations ceasing as soon as practicable, and Freeport will make a payment to Noble of $540 million. In addition, Noble can receive additional contingent payments from Freeport of $25 million and $50 million, respectively, depending upon the average price of oil over a 12 month period. Noble also expects to realize over $100 million in direct cost savings as a result of the contract terminations through crew reductions and stacking procedures. Freeport recently announced a restructuring of its oil and gas business, which is operated through FMOG. As disclosed in Freeport’s public filings, FMOG has substantial debt and has been negatively impacted by the crash in oil prices. “This agreement represents a favorable resolution for Noble shareholders.” said David W. Williams, Chairman, President and Chief Executive Officer, Noble Corporation plc. “By accelerating the contract value and removing counterparty risk and potential downtime exposure over the remaining term of the contracts, Noble will be able to secure the economic benefit of these contracts, particularly when factoring in the significant cost savings available. Given the financial headwinds facing our client, we are pleased to have resolved this matter in this manner, thus protecting our margins, monetizing the remaining term under the contracts and increasing our already robust financial flexibility.” Freeport can make the $540 million payment through a combination of cash, Freeport shares and up to $200 million in near-term Noble bonds. Through this arrangement, Noble expects to realize the full value of such payment.

10 May 2016

Noble Corporation plc Announces Agreement with Freeport-McMoRan

Noble Corporation plc (NYSE: NE) today announced an agreement with its client, Freeport-McMoRan Oil & Gas LLC (FMOG), and FMOG’s parent company, Freeport-McMoRan Inc. (Freeport), in connection with the drilling contracts for the drillships Noble Sam Croft and Noble Tom Madden, which were scheduled to terminate in July and November 2017, respectively. Pursuant to the agreement, the contracts will be .... [+ read more] terminated, with operations ceasing as soon as practicable, and Freeport will make a payment to Noble of $540 million. In addition, Noble can receive additional contingent payments from Freeport of $25 million and $50 million, respectively, depending upon the average price of oil over a 12 month period. Noble also expects to realize over $100 million in direct cost savings as a result of the contract terminations through crew reductions and stacking procedures. Freeport recently announced a restructuring of its oil and gas business, which is operated through FMOG. As disclosed in Freeport’s public filings, FMOG has substantial debt and has been negatively impacted by the crash in oil prices. “This agreement represents a favorable resolution for Noble shareholders.” said David W. Williams, Chairman, President and Chief Executive Officer, Noble Corporation plc. “By accelerating the contract value and removing counterparty risk and potential downtime exposure over the remaining term of the contracts, Noble will be able to secure the economic benefit of these contracts, particularly when factoring in the significant cost savings available. Given the financial headwinds facing our client, we are pleased to have resolved this matter in this manner, thus protecting our margins, monetizing the remaining term under the contracts and increasing our already robust financial flexibility.” Freeport can make the $540 million payment through a combination of cash, Freeport shares and up to $200 million in near-term Noble bonds. Through this arrangement, Noble expects to realize the full value of such payment.

9 May 2016

Kosmos Energy Announces Significant Gas Discovery Offshore Senegal

Kosmos Energy (NYSE: KOS) announced today that its Teranga-1 exploration well offshore Senegal has made a significant gas discovery. Located in the Cayar Offshore Profond block approximately 65 kilometers northwest of Dakar in nearly 1,800 meters of water, the Teranga-1 well was drilled to a total depth of 4,485 meters. The well encountered 31 meters (102 feet) of net gas .... [+ read more] pay in good quality reservoir in the Lower Cenomanian objective. Well results confirm that a prolific inboard gas fairway extends approximately 200 kilometers from the Marsouin-1 well in Mauritania through the Greater Tortue area on the maritime boundary to the Teranga-1 well in Senegal. Kosmos has now drilled five consecutive successful exploration and appraisal wells in this fairway with a 100 percent success rate. In the process, the company has discovered a gross Pmean resource of approximately 25 Tcf and estimates the fairway may hold more than 50 Tcf of resource potential. Andrew G. Inglis, chairman and chief executive officer, said: “Our continuing exploration success demonstrates we have opened a super-major scale basin offshore Mauritania and Senegal with world-class resource potential. Given the scale and quality of the gas resource discovered along the inboard trend, our focus is to move this resource through to development. Our forward exploration plan is to mature the two independent tests with oil potential in northern Mauritania and in the outboard of Mauritania and Senegal for drilling in 2017.”

6 May 2016

Atwood Falcon to be Sold for Scrap

According to Atwood Oceanic’s (“Atwood”) 10Q filing as per 31/3/2016, the Atwood Falcon completed its contract commitment with BHP Billiton in early March 2016. Based on a lack of contracting opportunities Atwood determined that future work for the unit was unlikely. Following mobilization to international waters on March 24th 2016, Atwood executed a sale and recycling agreement with a third a .... [+ read more] party, which will now demolish and recycle the drilling rig.

2 May 2016

Byron SM 71 #1 Oil and Gas Discovery

Byron Energy Ltd (ASX: BYE) (“Byron” or the “Company”) is pleased to provide an update on the Byron Energy SM71 #1 (“SM71 #1”) oil and gas discovery well located in the Gulf of Mexico in South Marsh Island Block 71 (“SM71”). Since the last report, on 27 April 2016, the well has been deepened, to the predrill planned total depth of .... [+ read more] 7,477 feet measured depth/6,915 feet true vertical depth and wireline logs have been run over the deeper portion of the well. The processed open hole porosity logs from this deepened section of the well indicate the presence of a very high porosity gas or gas condensate reservoir from 7,212 feet to 7,226 feet measured depth. A 5” liner will now be run and cemented in place over the deeper portion of the SM71 #1 well. As previously reported, the SM71 #1 well encountered 132 feet of TVT net oil pay in the I3 Sand, J Sand and D5 Sands. The final, processed version of the logs run over these three sands has now been received and confirm the previously reported net TVT pay count. Additionally, Isotube sample analysis indicates the likely presence of light, sweet crude oil from all three sand intervals. Current operations are preparing to run 5" liner over the deeper portion of the well before suspending the well for future production. It is expected that the rig will be demobilised within 10 days after mud line suspension operations are completed.

27 Apr 2016

Manora Oil Development Completed

Tap Oil Limited (ASX:TAP) provides the following update on the Manora Oil Development in the Northern Gulf of Thailand (Tap 30% interest). Mubadala Petroleum, Operator of the Manora Oil Development joint venture, has advised that drilling of the MNA-15 and MNA-16 development wells has now been completed. The MNA-15 and MNA-16 wells have been drilled to final total depths of 2,566m .... [+ read more] and 2,998m (measured depth) respectively and completed with electric submersible pumps (ESPs). Drilling and completion of the two wells was completed in 38 days. Both development wells were targeted to the east fault block of the Manora oilfield. The MNA-15 well found 44 m of oil pay in three separate reservoirs. It will be completed as a four zone selective completion produced by an ESP installed on a Y-block. The MNA-16 well found 37 m oil pay in four separate reservoirs. It will be completed as a six zone selective completion produced by an ESP installed on a Y-block. MNA-15 is expected to commence production in the last week in April when the rig leaves the platform. MNA-16 is expected to commence production during the first week in May once it is connected to the production system. Production from the two wells is expected to return Manora to its plateau rate of 15,000 bopd gross (4,500 bopd net to TAP). The Atwood Orca rig has now moved off location. The Atwood Orca is expected to commence drilling of the Sri Trang-1 exploration well in the Reservation Area of the G1/48 Concession in mid May 2016. Tap has 2P reserves of 4 mmbbls (13.2 mmbbls gross) as at 31 December 2015 booked for Manora (see annual report ASX release 22 April 2016). Tap will review these reserves and contingent resources following development drilling and production performance.

27 Apr 2016

Total begins exploratory drilling

On Friday, April 22, 2016, the drillship Noble Globetrotter II left the Bulgarian port of Burgas, to travel to the location of the Polshkov-1 well for the first deep offshore exploratory drilling in Bulgarian waters. Xavier Faugeras, General Manager, Total E&P Bulgaria, presented the drillship at an official port ceremony on Tuesday, April 19, 2016. The event, which included the .... [+ read more] symbolic Bulgarian tradition of spilling water in front of the ship’s bow for good luck, was attended by the Prime Minister of Bulgaria, Boyko Borissov, Deputy Prime Minister for EU Funds and Economic Policies Mr. Tomislav Donchev, Minister of Energy Temenuzhka Petkova, Minister of Environment and Water Ivelina Vassileva, Minister of Transport Ivaylo Moskovski, Chairperson of the Parliamentary Energy Committee Mr. Delian Dobrev and other officials. “The arrival of the drillship marks a major step in the realization of the exploration program of Block 1-21 Khan Asparuh,” Mr. Faugeras pointed out. “This drilling is aimed at testing the presence of hydrocarbons on a structure identified on the block and will yield additional information to calibrate the models of the exploration team.” Total E&P Bulgaria along with its partners OMV Offshore Bulgaria GmbH and Repsol Bulgaria B.V. are committed to continue executing this important project for Bulgaria in the most professional and efficient manner.

26 Apr 2016

Operational Update for WilPhoenix

Reference is made to Awilco Drilling's press release of 4 April 2016. The yard stay for WilPhoenix is now complete and Awilco Drilling considers the rig to be, in all respects, ready to drill awaiting Apache North Sea Ltd's instructions to resume operations. The total cost for the yard stay and the installation of the new BOP was below the budget .... [+ read more] of USD 42.5 million. In accordance with the contract, Awilco Drilling considers that WilPhoenix is on standby rate from the completion of the yard stay. Apache North Sea Ltd. does not agree that the rig is ready to drill nor that Awilco Drilling is entitled to standby rate at this point. A further update will be released as and when appropriate.

25 Apr 2016

Ocean Rig Announces Acquisition of Ultra Deepwater Drillship

Ocean Rig UDW Inc. (NASDAQ:ORIG) (“Ocean Rig” or the “Company”), a global provider of offshore deepwater drilling services, announced today that one of its subsidiaries has acquired the 6th generation ultra deepwater drillship Cerrado, being sold through an auction, for a purchase price of $65 million, which will be funded with available cash on hand. The drillship was built at Samsung .... [+ read more] Heavy Industries in 2011 to similar design specifications as the Company’s existing 6 th generation drillships built at Samsung, and will be renamed the Ocean Rig Paros upon its delivery to Ocean Rig. Another subsidiary of the Company has been acting as the manager of the drillship for its previous owners. The transaction is expected to close upon completion of the judicial auction procedure.

20 Apr 2016

Byron SM 71 #1 Oil and Gas Discovery

Byron Energy Ltd (ASX: BYE) (“Byron” or the “Company”) is pleased to announce that the Byron Energy SM 71 #1 (“SM-71 #1”) well located in the Gulf of Mexico in South Marsh Island Block 71 (“SM 71”) has reached a final total depth at 6,843 feet (2,086 metres) Measured Depth or 6,477 feet (1,974 metres) True Vertical Depth. During drilling of .... [+ read more] the SM 71 #1 well three discrete hydrocarbon bearing sands were intersected. Preliminary evaluation has been completed using Gamma Ray/ Resistivity Logging While Drilling (LWD) tools. Indications of oil were seen on cuttings from the D5 sand interval and all hydrocarbon bearing zones demonstrate elevated wet gas readings. Based on preliminary interpretation of these results it appears that a significant proportion of these hydrocarbon bearing sands will result in net hydrocarbon pay, however net pay counts cannot be determined until a porosity log is run and may be determined to be less than the gross sand amounts reported here. Currently, Byron is running in to the hole with a bit to address excess wall-cake build up and verify the hole's condition prior to running porosity logs. Whilst drilling to TD below the D5 Sand, a pressure transition was intersected which required an increase in mud weight to control the well. The higher mudweights suppressed gas ingress, but will require additional conditioning of the wellbore. The D5 Sand, which was the primary target of this well exhibits excellent quality, is within the range of predrill expectations, and confirms the RTM technology used to delineate the prospect. The J Sand, which was a secondary target, was found within predrill expectations and was intersected 220 feet (67 metres) up-dip of the highest productive well in the J Sand interval. The I3 Sand, which was not included in the predrill estimates, will enhance the project economics. The I3 sand interval does not appear to have been produced in offset wells on SM 71. The preliminary results from these three discrete hydrocarbon intervals are considered of commercial value to warrant the completion and ultimate production of the well. This will be done by the running the 7 ?” production liner and suspension of the well for future production. Byron will now move forward with development planning and has already initiated discussions with an offset operator to cost effectively produce the hydrocarbons from this well. The SM 71 #1 well is the second well to be drilled as part of Byron’s farm-out to Otto Energy Limited (“Otto”) (ASX: OEL), announced on 11 December 2015. The SM 71 #1 well targeted two objective sands. The first target was the J Sand, which has been assigned by Collarini and Associates gross proved and probable undeveloped reserves of 0.8 million barrels of oil and 0.5 Bcf of gas, equivalent to 0.7 million barrels of oil and 0.4 Bcf of gas net to Byron’s existing 81.25% Working Interest (“WI”). The primary target was the D5 sand, which has been assigned, by Collarini and Associates, gross prospective resources of 5.6 million barrels of oil and 4.1 Bcf of gas, equivalent to 4.6 million barrels of oil and 3.4 bcf of gas net to Byron’s existing 100% WI and 81.25% Net Revenue Interest (“NRI”)*. Byron, through its wholly owned subsidiary Byron Energy Inc. (the operator), currently has a 100% working interest and an 81.25% net revenue interest in SM 71, located offshore Louisiana, 250 km southwest of New Orleans, Louisiana, USA, in water depth of approximately 131 feet (40 metres). Pursuant to the farm-out agreement, Otto will pay 66.67% of the SM 71 #1 estimated dry hole costs ($US 4.5 million) to earn a 50% working interest in the SM 71 and SM 70 leases. Otto’s promoted drilling exposure will be capped at $US 3.0 million net to Otto, after which both companies will bear their own proportionate share. The well has been drilled in line with the pre-drill cost estimate of $US 4.5m gross. Otto has also reimbursed Byron $US 0.9 million for past costs incurred at SM 71. If Otto earns an interest in the SM 71 and SM 70 blocks, Byron’s working and net revenue interests will be reduced by 50% at the earn-in point, to 50% and 40.625% respectively.

19 Apr 2016

Drilling permit for well 30/11-13 in production licence 035/272

The Norwegian Petroleum Directorate has granted Statoil Petroleum AS a drilling permit for well 30/11-13, cf. Section 8 of the Resource Management Regulations. Well 30/11-13 will be drilled from the Songa Delta drilling facility at position 60°09’55.78’’ north 02°35’35.13’’ east in production licence 035. The drilling programme for well 30/11-13 relates to the drilling of a wildcat well. Statoil Petroleum .... [+ read more] AS is the operator with an ownership interest of 50 per cent and Det norske oljeselskap AS is a licensee with an ownership interest of 50 per cent. The area in this licence consists of part of block 30/11. Production licence 035 was awarded in the 2nd licensing round on 14 November 1969. This is the thirteenth exploration well to be drilled within the licence area. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

19 Apr 2016

Transocean Ltd. Announces Ultra-Deepwater Drillship Delay

Transocean Ltd. (NYSE: RIG) announced today an agreement with Sembcorp Marine's subsidiary, Jurong Shipyard Ptd Ltd, to defer the delivery and related final payments of two dynamically positioned ultra-deepwater drillships. The proprietary Jurong Espadon 3T designed rigs are now scheduled to be delivered during the first and third quarter of 2020. .... [+ read more]

19 Apr 2016

Transocean Ltd. Announces Ultra-Deepwater Drillship Delay

Transocean Ltd. (NYSE: RIG) announced today an agreement with Sembcorp Marine's subsidiary, Jurong Shipyard Ptd Ltd, to defer the delivery and related final payments of two dynamically positioned ultra-deepwater drillships. The proprietary Jurong Espadon 3T designed rigs are now scheduled to be delivered during the first and third quarter of 2020. .... [+ read more]

18 Apr 2016

Repair work completed

Repair of Polyarnaya Zvezda and Severnoye Siyaniye, semi-submersible mobile offshore drilling units (MODU) of the sixth generation, has been completed under survey of Russian Maritime Register of Shipping (RS) at Yantai CIMC Raffles Offshore Shipyard Ltd. in Yantai, China. Mr. Konstantin Palnikov, RS Director General, attended the ceremony of MODUs delivery to customer, which was held on 15 April 2016. .... [+ read more] During survey of the MODU repair and equipment replacement RS specialists performed docking survey, inspection of hull structures, ship machinery and disassembled devices. The tests and operation checks of the machinery, equipment and ship systems, as well as platform sea trials, were successful. Currently their presentation to the next survey has been completed, and the MODUs are ready to continue their work. Structurally, Polyarnaya Zvezda and Severnoye Siyaniye are self-propelled floating catamaran structures with two pontoons and six stabilizing columns, supporting the top hull and topside. The platforms are suitable for exploration and production drilling of gas and oil-and-gas wells of up to 7500 m in depth at sea depths from 70 to 500 m in broken ice up to 70 cm thick. Their equipment is designed to efficiently and safely operate at ambient temperatures up to - 30 ° C. Polyarnaya Zvezda and Severnoye Siyaniye platforms were built under RS survey at Vyborgskiy shipyard for operation in Arctic conditions. RS class notation: KM? [1] AUT1-ICS EPP semi-submersible ice-resistant MODU. Before the repair they were operating at the offshore area of Sakhalin.

18 Apr 2016

Repair work completed

Repair of Polyarnaya Zvezda and Severnoye Siyaniye, semi-submersible mobile offshore drilling units (MODU) of the sixth generation, has been completed under survey of Russian Maritime Register of Shipping (RS) at Yantai CIMC Raffles Offshore Shipyard Ltd. in Yantai, China. Mr. Konstantin Palnikov, RS Director General, attended the ceremony of MODUs delivery to customer, which was held on 15 April 2016. During .... [+ read more] survey of the MODU repair and equipment replacement RS specialists performed docking survey, inspection of hull structures, ship machinery and disassembled devices. The tests and operation checks of the machinery, equipment and ship systems, as well as platform sea trials, were successful. Currently their presentation to the next survey has been completed, and the MODUs are ready to continue their work. Structurally, Polyarnaya Zvezda and Severnoye Siyaniye are self-propelled floating catamaran structures with two pontoons and six stabilizing columns, supporting the top hull and topside. The platforms are suitable for exploration and production drilling of gas and oil-and-gas wells of up to 7500 m in depth at sea depths from 70 to 500 m in broken ice up to 70 cm thick. Their equipment is designed to efficiently and safely operate at ambient temperatures up to - 30 ° C. Polyarnaya Zvezda and Severnoye Siyaniye platforms were built under RS survey at Vyborgskiy shipyard for operation in Arctic conditions. RS class notation: KM? [1] AUT1-ICS EPP semi-submersible ice-resistant MODU. Before the repair they were operating at the offshore area of Sakhalin.

18 Apr 2016

Spud of SNE-4 appraisal well

The SNE 4 well, which is 5 km south-east of the SNE-1 discovery well, was spudded over the weekend to appraise the eastern extent of the field. The SNE-4 well is located in 940m water depth and will be drilled to a total depth of 3,020m TVD. It will be drilled and logged and is expected to take approximately four weeks .... [+ read more] to complete. This further appraisal well in the SNE field will assist in progressing towards confirming the commercial viability of the field.

16 Apr 2016

Ralph Coffman on route to Suriname

Petronas, the national oil company of Malaysia and the German oil company Deutsche Erdoel AG (DEA) will start drilling the exploration well Roselle-I in offshore Block 52 in May. The oilrig Ralph Coffman – Rowan which is deployed for the exploration activities left Chaguaramas Bay, Trinidad on 18 April. The voyage to Suriname takes about 12 days. .... [+ read more]

15 Apr 2016

Sevan Developer Delivery Deferral Agreement Second Extension

Reference is made to the press release dated 30 October 2015 regarding the Sevan Developer deferral agreement. Sevan Drilling and Cosco have agreed to exercise the second six-month option to extend the deferral agreement to 15 October 2016. The final delivery instalment has been amended to $473.4 million, representing 90% of the $526.0 million contract price and Cosco will refund $26.3 .... [+ read more] million, or 5% of the contract price, plus other associated costs to Sevan Drilling by 25 May 2016. The agreement can be amended further upon the expiration of the option period. Other terms and conditions under the deferral agreement dated 15 October 2014, including termination rights, remain unchanged.

15 Apr 2016

Hai Yang Shi You 937 Won a 180-day Renewal Drilling Contract in Indonesia

Recently, Hai Yang Shi You 937 was awarded a 180-day contract for renewal of drilling operations with SAKA, upon completion of the 2015-year drilling contract with SAKA. .... [+ read more]

14 Apr 2016

Drilling permit for well 16/1-26 A in production licence 001 B

The Norwegian Petroleum Directorate has granted Det norske oljeselskap AS a drilling permit for well 16/1-26 A, cf. Section 8 of the Resource Management Regulations. Well 16/1-26 A will be drilled from the Maersk Interceptor drilling facility at position 58°55’20.15’’ north 02°11’53.03’’ east in production licence 001 B. The drilling programme for the 16/1-26 A well relates to the drilling .... [+ read more] of an appraisal well on the 16/1-7 oil discovery, which is part of the Ivar Aasen field, where Det norske is the operator with an ownership interest of 34.7862 per cent. The other licensees are Statoil Petroleum AS with 41.4730 per cent, Bayerngas Norge AS with 12.3173 per cent, Wintershall Norge AS with 6.4615 per cent, VNG Norge AS with 3.0230 per cent, Lundin Norway AS with 1.3850 per cent and OMV (Norge) AS with 0.5540 per cent. The area in this licence consists of part of block 16/1. The well was drilled in the eastern part of the 16/1-7 discovery in the central part of the North Sea. Production licence 001 B was carved out of production licence 001 on 1 Sept. 1999. PL 001 was awarded on 1 Sept. 1965 (Round 1-A). This is the 11th exploration well to be drilled within the licence area. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

13 Apr 2016

Minor oil discovery and dry well southwest of the Oseberg South field in the North Sea - 30/11-11 S and 30/11-11 A

Statoil Petroleum AS, operator of production licence 035/272, is in the process of completing the drilling of wildcat wells 30/11-11 S and 30/11-11 A. The wells were drilled about two kilometres southeast of the 30/11-9 A discovery (Askja East) and 35 kilometres southwest of the Oseberg South facility in the North Sea. The primary exploration target for wells 30/11-11 S .... [+ read more] and 30/11-11 A was to prove petroleum in Upper to Middle Jurassic reservoir rocks (Tarbert formation) in two nearby fault blocks. The secondary exploration target was to prove petroleum in Middle Jurassic reservoir rocks (Ness formation). 30/11-11 S encountered a 25-metre oil column in the upper part of the Tarbert formation, of which 22 metres had moderate to good reservoir properties. 30/11-11 A encountered a corresponding reservoir in the Tarbert formation, but it is aquiferous with traces of hydrocarbons. The well is classified as dry. Both wells proved sandstones with moderate to good porosity in the Ness formation, but these were aquiferous. Preliminary estimation of the size of the discovery in well 30/11-11 S is between 0.2 and 0.5 million standard cubic metres (Sm3) of recoverable oil. Data acquisition and sampling have been carried out in both wells. The 30/11-11 S and 30/11-11 A wells were drilled to respective vertical depths of 3646 and 3334 metres below the sea surface and measured depths of 3646 and 3987 metres below the sea surface. 30/11-11 S was terminated in the Ness formation and 30/11-11 A was terminated in the Tarbert formation. The wells are the 12th and 13th exploration wells in production licence 035. The licence was awarded in the second licensing round in 1969. Water depth is 106 metres. The wells will be permanently plugged and abandoned. Wells 30/11-11 S and 30/11-11 A were drilled by the Songa Delta drilling facility. The results from the wells will not affect future drilling of the exploration campaign in the area. The campaign will continue with the same drilling facility in the same production licence, with wildcat well 30/11-12 S and potentially 30/11-12 A if the structure warrants an appraisal well.

13 Apr 2016

Drilling permit for wells 30/11-12 S and 30/11-12 A in production licence 035

The Norwegian Petroleum Directorate has granted Statoil Petroleum AS a drilling permit for wells 30/11-12 S and 30/11-12 A, cf. Section 8 of the Resource Management Regulations. Well 30/11-12 S will be drilled from the Songa Delta drilling facility at position 60°05’00.12’’ north 02°35’36,32’’ east in production licence 035. The drilling programme for well 30/11-12 S relates to drilling of .... [+ read more] a wildcat well. Well 30/11-12 A is an appraisal well that will be drilled in the event of a discovery. Statoil is the operator with an ownership interest of 50 per cent. Det norske oljeselskap ASA is a licensee with an ownership interest of 50 per cent. The area in this licence consists of part of block 30/11. Production licence 035 was awarded in licensing round 2-A on 14 November 1969. This is the eleventh exploration well to be drilled in the licence area. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

13 Apr 2016

Drilling permit for well 35/8-6 A in production licence 248

The Norwegian Petroleum Directorate has granted Wintershall Norge AS a drilling permit for well 35/8-6 A, cf. Section 8 of the Resource Management Regulations. Well 35/8-6 A will be drilled from the Borgland Dolphin drilling facility at position 61°19’41.65’’ north 03°20’17.11’’ east in production licence 248. The drilling programme for well 35/8-6 A relates to the drilling of a wildcat .... [+ read more] well. Wintershall Norge AS is the operator with an ownership interest of 60 per cent. Petoro AS is a licensee, with an ownership interest of 40 per cent. The area in this licence consists of part of block 35/8. Production licence 248 was awarded in the North Sea Awards on 4 June 1999. This is the sixth exploration well drilled within the licence area. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

13 Apr 2016

CIMC Raffles Held “KAN TAN QI HAO” Jackup Naming and Delivery Ceremony

On April 12, 2016, “KAN TAN QI HAO”, the 400ft JU2000E jackup, built by CIMC Raffles for Sinopec Shanghai Ofshore Petroleum Bureau, was delivered in Yantai CIMC Raffles. Classed by ABS, it can be operated in minus 20 Celsius with the length of 70.36 meters, width of 76 meters and design depth of 9.45 meters. It can drill up to 10668 .... [+ read more] meters with operation depth of 122 meters. As the first 400ft jackup drilling rig cooperated with Sinopec Shanghai Ofshore Petroleum Bureau, “KAN TAN QI HAO” reaches quantities of optimization and innovations in key-point technology, operational convenience and safety. The jackup will set off at the end of April.

13 Apr 2016

SM 71 #1 Well Drilling Ahead

Further to the release of 4 April 2016, Byron Energy Limited (“Byron”) (ASX:BYE) advises that the Byron Energy South Marsh Island 71 #1 (“SM 71 #1”), located in South Marsh Island Block 71 (“SM 71”), was drilled to a depth of 3,462 feet measured depth on 8 April 2016 where 10 3/4" casing was set and cemented in place the following .... [+ read more] day. The well is currently (at 7 PM USA Central Time, 12 April 2016) drilling ahead at 3,976 feet measured depth in 9 7/8” hole. The SM 71 #1 well is being drilled to test two objective sands on the southwest flank of a major salt dome in a water depth of 131 feet (40 metres) and has a planned total measured depth of approximately 7,451 feet (2,272 metres) and total vertical depth of 6,900 feet (2,104 metres). It is anticipated that the well will take 7 - 10 days, from today, to drill to total depth and evaluate. The SM 71 #1 well is the second well to be drilled as part of Byron’s farm-out to Otto Energy Limited (“Otto”) (ASX: OEL), announced on 11 December 2015. Byron, through its wholly owned subsidiary Byron Energy Inc. (the operator), currently has a 100% working interest and an 81.25% net revenue interest in SM 71. Pursuant to the farm-out agreement, Otto has paid 50% of the sunk costs and will pay 66.67% of the drilling cost to total depth in order to earn 50% WI in the SM 71 and SM 70 blocks. If Otto earns an interest in the SM 71 and SM 70 blocks, Byron’s working and net revenue interests will be reduced by 50% at the earn-in point, to 50% and 40.625% respectively.

11 Apr 2016

Commencement of drilling contract for Songa Encourage

Songa Encourage commenced drilling operations on 11 April 2016 under its eight-year drilling contract with Statoil on the Norwegian continental shelf. The rig is now on operational day rate and working on the Skuld field. Songa Encourage is the third rig in a series of four Category D rigs, specifically built for, and contracted to Statoil. .... [+ read more]

7 Apr 2016

Statoil has received consent to drill the two exploration wells 30/11-12 S and 30/11-12 A in the North Sea

Statoil is the operator for production licences 272 and 035. Drilling is estimated to last for 45 days, depending on whether a find is made. Drilling will be performed by Songa Delta, which is operated by Songa Offshore. The facility was issued with an Acknowledgement of Compliance (AoC) by the PSA in November 2012. The PSA has now given Statoil .... [+ read more] consent for exploration drilling in accordance with the company's application.

7 Apr 2016

The PSA has given Statoil consent to use the Stena Don mobile drilling facility for drilling and completion of wells 35/11-B-22 and B-13

Stena Don is operated by Stena Drilling, and is a Sonat/Hitachi-designed, semi-submersible drilling facility, built in 2001. The facility received Acknowledgement of Compliance (AoC) in March 2002. Fram is an oil field in the northern North Sea around 20 kilometres north of Troll. Water depth in the area is around 350 metres. The Petroleum Safety Authority Norway has now .... [+ read more] granted consent to use Stena Don on the Fram field in accordance with Statoil's application.

6 Apr 2016

OMV operated successful horizontal appraisal well for Wisting in Norway

OMV has successfully completed drilling and testing of the Wisting Central II appraisal well. The horizontal well was drilled in the Wisting field in the Barents Sea, about 310 km north of Hammerfest. The Wisting field is the northernmost oil discovery in Norway. Wisting Central II is the fifth well in the production license PL537, which was awarded in the 20th .... [+ read more] licensing round in 2009. The well objectives were to confirm the potential of the discovery by proving the presence of hydrocarbons in the undrilled Wisting Central South and Central West segments, and to prove the technical concept of long-reach horizontal wells in a shallow reservoir, about 250 meters below seabed. The possibility to drill such wells is needed to establish the basis for a viable development of the Wisting discovery. A well test was performed and flow rates reached just above 5,000 boe/d. The well results are expected to provide an increase of in-place volumes in the Central South and Central West segments, and further reduce the overall uncertainty of contingent resources in PL537. The Wisting Central II well is the first horizontal appraisal well in the Barents Sea and sets a new drilling record; it is the shallowest horizontal offshore well drilled from a floating drilling facility. Water depth at Wisting is 402 meters. The well started vertically and was successfully steered into a horizontal orientation within a 250 meters depth interval. The total well length is 2,354 meters and the horizontal section measures 1,402 meters. Advanced data collection and geo-steering was conducted through the entire horizontal phase. The well was spudded on January 15, 2016, by the semisubmersible rig Transocean Spitsbergen. The well test was finalized end of March and the well will now be permanently plugged and abandoned. "OMV is very satisfied with the well test results, which are promising. This well is an important milestone towards a future field development on Wisting" said Johann Pleininger, OMV Executive Board member responsible for Upstream. OMV (Norge) AS as operator has 25% share in the PL537 license. Joint venture partners are Petoro (20%), Idemitsu (20%), Tullow (20%) and Statoil (15%).

6 Apr 2016

Delineation of the 7324/8-1 (Wisting) oil discovery in the Barents Sea – 7324/7-3

OMV Norge AS, operator of production licence 537, is in the process of completing the drilling of appraisal well 7324/7-3 S on the 7324/8-1 (Wisting) oil discovery. The well was drilled about 310 km north of Hammerfest. The discovery was proven in reservoir rocks from the Middle and Early Jurassic (upper Realgrunnen subgroup) in 2013. Before well 7324/7-3 S was .... [+ read more] drilled, the operator's resource estimate for the Wisting area was between 32 and 80 million standard cubic metres (Sm3) of recoverable oil equivalents. The objective of the well was to confirm the size of the 7324/8-1 discovery in the "Wisting Central Sør" and "Wisting Central Vest" segments. An additional objective was to test whether the well can be drilled horizontally in the shallow reservoir approximately 250 m below the seafloor, as well as to formation-test the Stø formation. The well was drilled with a horizontal section of about 1400 metres. It encountered sandstones in the Stø and Fruholmen formations. The "Wisting Central Sør" segment has good reservoir properties in the Stø formation and moderate reservoir properties in the Fruholmen formation. Reservoir quality in the Stø formation in the "Wisting Central Vest" segment is also good. The oil/water contact was not encountered. The estimate of the discovery size will be updated based on evaluation of the new well data. The result will be important for further maturation of the Wisting area, as regards a potential development. Extensive data acquisition and sampling have been carried out. A successful formation test was conducted in the Stø formation in the "Wisting Central Vest" segment. Maximum production rates were 762 Sm3 of oil and 48 310 Sm3 of associated gas per flow day through a 104/64-inch nozzle opening. The gas/oil ratio is 73 Sm3/Sm3. The formation test revealed production and flow properties that were mainly good. This is the fifth exploration well in production licence 537. The licence was awarded in the 20th licensing round in 2009. Appraisal well 7324/7-3 S was drilled to vertical and measured depths of 673 and 2314 metres, respectively, below the sea surface, and was terminated in the Stø formation from the Middle Jurassic Age. Water depth in the area is 402 metres. The well will now be permanently plugged and abandoned.

6 Apr 2016

Hercules Offshore, Inc. Announces Contract Extension for the Hercules 266

Hercules Offshore, Inc. (NASDAQ: HERO) announced today that it received a notice from Saudi Aramco extending the contract for the Hercules 266 to June 30, 2016. The dayrate for the Hercules 266 will remain at $63,650 per day through the term of the contract extension. .... [+ read more]

5 Apr 2016

Operations Update: UK Central North Sea Licence P2013

Zennor Pathway Limited is pleased to announce that the Transocean Sedco 704 drilling rig spudded well 21/5c-7 on 5th April. This is an appraisal well on the Finlaggan Discovery. Zennor Pathway Limited (Operator) holds a 100% interest in the Licence. .... [+ read more]

4 Apr 2016

SM 71 #1 Well Spuds in Gulf of Mexico

Further to the release of 30 March 2016, Byron Energy Limited (“Byron”) advises that the contracted jack-up drilling rig, Hercules 205, spudded the Byron Energy South Marsh Island 71 #1 (“SM 71 #1) well located in South Marsh Island Block 71 (“SM 71”) on 3 April 2016, at approximately 11:30 AM (USA Central Time). Current operations at the SM 71 #1 .... [+ read more] well are drilling ahead at 671 feet measured depth. 20-inch conductor casing will be set at 800 feet measured depth. The SM 71 #1 well is being drilled to test two objective sands in the southwest corner of a major salt dome in a water depth of 131 feet (40 metres) and has a planned total measured depth of approximately 7.451 feet (2,272 metres) and total vertical depth of 6,900 feet (2,104 metres). It is anticipated that the well will take approximately 20 days to drill and evaluate. The SM 71 #1 well is the second well to be drilled as part of Byron’s farm-out to Otto Energy Limited (“Otto”) (ASX: OEL), announced on 11 December 2015. In order to earn a 50% working interest (equal to a 40.625% net revenue interest) in the South Marsh Island block (“SM 71”), Otto will contribute 66.67% of the total estimated costs of the SM 71 #1 well of $US 4.5 million ($US2.99 million Otto and $US 1.51 million Byron). Any costs above $US 4.5 million in respect of the SM 71 #1 well and all future expenditure in SM 71 will be in accordance with Byron’s and Otto’s respective working interest (Byron 50%/Otto 50%). Otto has also paid Byron $903,610 for past cost reimbursement in the SM 71 project. Byron, through its wholly owned subsidiary Byron Energy Inc. (the operator), currently has a 100% working interest and an 81.25% net revenue interest in SM 71. If Otto earns an interest in the SM 71 block, Byron’s working and net revenue interests will be reduced by 50% at the earn-in point, to 50% and 40.625% respectively.

4 Apr 2016

AWDR - Operational Update for WilPhoenix

Reference is made to Awilco Drilling's press release of 29 February 2016 and the Q4 2015 presentation given on 11 February 2016. The yard stay for WilPhoenix is taking longer than anticipated and in the meantime the rig remains berthed at Hartlepool on zero dayrate. Awilco Drilling is working expediently to close out the yard stay in co-operation with Apache North .... [+ read more] Sea Ltd. The estimated total cost for the yard stay and the installation of the new BOP continues to be below the budget of USD 42.5 million. A further update will be released upon re-commencement of the rig's remaining 22 months of its three-year contract. WilPhoenix is one of Awilco Drilling's two enhanced pacesetter semi-submersibles and is equipped for drilling in water depths up to 1,200 ft.

1 Apr 2016

Island Drilling Company ASA is addressing its long term financing structure

Island Drilling Company ASA (the "Company") (OTC: ISDRILL) announces its decision to formally address its long term financing structure with the aim of restructuring the Company's balance sheet. The Company's semi-submersible rig, 'Island Innovator' has come off its charter party for Lundin Norway ASA, and no new charter party has been found for the rig. A restructuring of the Company's balance .... [+ read more] sheet is therefore deemed necessary to enable the Company to come through the current market challenges, and the Company is initiating discussions with its finance providers in this respect. While these discussions are ongoing, the Company has decided to halt all payments of interest and amortization to all of its finance providers. The Company will work with its finance providers to reach a sustainable solution for the Company. While the Company is confident that such sustainable solution will be reached with the relevant stakeholders, there can be no assurance or guarantee that such final solution will be reached. During the discussions with the finance providers, the Company will continue to operate normally in all other respect. The liquidity of the Company remains stable for the period to come in anticipation of a sustainable solution with the finance providers.

31 Mar 2016

Delivery of Songa Enabler

Songa Offshore has today taken delivery of Songa Enabler from Daewoo Shipbuilding & Marine Engineering (DSME) in Korea. Songa Enabler will shortly depart South Korea en route to Norway for commencement of an eight-year drilling contract with Statoil, with the first assignment on the Snøhvit field. The transit will take place with tow-assist and the rig will arrive in Norway .... [+ read more] with all third party equipment installed and ready for the client's final acceptance testing. Commencement of drilling operations is expected to take place in third quarter 2016. Songa Enabler is a sixth generation, high specification, harsh environment, fully winterized, midwater rig designed for efficient year around drilling, completion, testing and intervention operations in water depths up to 500 meters. The rig is certified DP3 and is equipped with a "state-of-the-art" drill-floor and an efficient layout with improved safety and working environment features. Songa Enabler is the last rig in a series of four Category D rigs specifically built for and contracted to Statoil.

30 Mar 2016

Sevan Drilling Ltd: Sevan Drilling Ltd amends drilling contracts and secures new employment for Sevan Driller

Reference is made to the Fourth Quarter Earnings Release on February 25, 2016, Sevan Drilling Limited ("Sevan Drilling" or the "Company") amended contracts for the Sevan Driller and Sevan Brasil with Petroleo Brasileiro SA ("Petrobras") and secured short-term employment for Sevan Driller in Brazil with Shell do Brasil ("Shell") commencing in the second quarter 2016. In December 2015, the Sevan .... [+ read more] Driller contract was suspended by Petrobras as part of the ongoing commercial negotiations for both of Sevan Drilling's units employed with Petrobras. Today, Petrobras and Sevan Drilling executed an early termination of the Sevan Driller contract and reduction of the contract dayrate on the Sevan Brasil. The Company determined on balance that this was the preferred alternative to potentially having both contracts terminated and exposing the Company to a protracted legal challenge with an uncertain outcome. As a result, the Company was able to preserve $220 million of contracted revenue backlog for the Sevan Brasil contract and to allow the Sevan Driller to obtain alternative employment. The Sevan Brasil contract dayrate has been reduced to US$250,000 per day effective 26 February 2016 through the remaining term of the contract, ending July 2018 and a portion of the dayrate continues to be denominated in Brasilian Reals. The Sevan Driller contract was mutually agreed to be cancelled effective from 1 December 2015. Subsequent to the effective cancellation of the contact for the Sevan Driller, the unit has been awarded a well intervention contract by Shell in Brazil for 60 days with two 30 day options commencing in the second quarter of 2016, adding approximately US$11 million in revenue backlog. Daily operating cost is expected to be significantly lower as the rig will perform non-drilling activities for Shell. As of 26 February 2016, the Company's total contracted revenue backlog is now estimated at $509 million, including the extension of the Sevan Louisiana contract amended in November 2014.

30 Mar 2016

The 2nd Ultra-deep-water Semisubmersible Drilling Rig Mating In CIMC Raffles

On March 30th 2016, Frigstad Kristiansand, the second ultra-deep-water semisubmersible drilling rig build by CIMC Raffles for Frigstad completed mating in Yantai Shipyard. As one of the deepest operating and drilling semisubmersible rigs, Frigstad Kristiansand can be operated up to 3,658 meter and drilled to 15,250 meter. Equipped with DP3 system and dual derrick, it isclassed by DNV. .... [+ read more] Frigstad Kristiansand adopts Frigstad D90 basic design. Meanwhile its detailed and production designs are completed by CIMC Raffles. Learned from Frigstad Deepwater Rig Alfa, CIMC Raffles realized several project improvements. Compared with Frigstad Deepwater Rig Alfa, Frigstad Kristiansand reduces to 2.5 million working hours. Completion of MCR is over 30% before launching.

29 Mar 2016

Mærsk Deliverer contract cancelled

Maersk Drilling has received a notice of early contract termination from Cabinda Gulf Oil Company Limited (CABGOC), Chevron Corporation’s affiliate in Angola, for the ultra-deepwater semi-submersible Mærsk Deliverer. The contract was due to end in December 2016, and as per the contract, Maersk Drilling is entitled to receive compensation for the remaining part of the contract. The contract cancellation will be .... [+ read more] financially neutral to Maersk Drilling. With regret we take note of the contract termination, and it is a reminder of the very challenging conditions in the offshore rig market with oil companies restraining activities and capital spending in response to the lower oil price environment. We expect to base the rig in West Africa, and will continue to explore opportunities with our customers in primarily West and East Africa, which remain strategic markets for us,” says Head of Global Sales, Michael Reimer Mortensen. Mærsk Deliverer has been on contract with CABGOC since May 2012. Mærsk Deliverer was built in 2009 and is designed for year-round operation in areas such as Brazil, the Gulf of Mexico, West and East Africa and Asia Pacific at water depths of up to 3,000 m (10,000 ft.).

28 Mar 2016

Delivery of Cantarell I and II

Offshore Drilling Holding S.A. (“ODH” or “The Company”) announces that on March 24, 2016 the company took delivery of the first two Jackup rigs: Cantarell I and Cantarell II from Keppel FELS shipyard. Final payment of the Construction Contracts was done with the support of several international banks that structured, closed and funded a project finance loan, backed by the assets .... [+ read more] and the revenues from the respective charter contracts with PEMEX. It is important to state that the shallow water is a division of Offshore Drilling Holding, but it is not part of the structure of the Bond. Cantarell I and Cantarell II departed today March 28, 2016 from Singapore to Mexico on board a heavy lift vessel and are scheduled to commence operations in the Gulf of Mexico on August 1st, 2016, under the same terms previously announced by the Company. José Ramiro Garza, CEO of ODH states: “We are living in challenging times in the oil industry worldwide, particularly in the offshore drilling services market. Fortunately, we were able to complete the payment and delivery of our first two premium Jackup rigs and now we are scheduled to commence operating in August this year. We continue working hard and doing what is in our hands to accomplish the work plan previously announced by the Company in connection to our operations in shallow and ultra-deep water.”

28 Mar 2016

Delivery of Cantarell I and II

Offshore Drilling Holding S.A. (“ODH” or “The Company”) announces that on March 24, 2016 the company took delivery of the first two Jackup rigs: Cantarell I and Cantarell II from Keppel FELS shipyard. Final payment of the Construction Contracts was done with the support of several international banks that structured, closed and funded a project finance loan, backed by the assets .... [+ read more] and the revenues from the respective charter contracts with PEMEX. It is important to state that the shallow water is a division of Offshore Drilling Holding, but it is not part of the structure of the Bond. Cantarell I and Cantarell II departed today March 28, 2016 from Singapore to Mexico on board a heavy lift vessel and are scheduled to commence operations in the Gulf of Mexico on August 1st, 2016, under the same terms previously announced by the Company. José Ramiro Garza, CEO of ODH states: “We are living in challenging times in the oil industry worldwide, particularly in the offshore drilling services market. Fortunately, we were able to complete the payment and delivery of our first two premium Jackup rigs and now we are scheduled to commence operating in August this year. We continue working hard and doing what is in our hands to accomplish the work plan previously announced by the Company in connection to our operations in shallow and ultra-deep water.”

28 Mar 2016

Exploration well on Bakassi West, Cameroon, Manatee-1, Well Results

SDX Energy Inc. (“SDX” or the “Company”) (TSX VENTURE: SDX), an oil & gas exploration and production company with assets in Egypt & Cameroon, hereby announces that drilling operations have been completed on the Manatee-1 exploration well in Cameroon. The well is operated by Dana Petroleum and SDX holds 35% working interest (38.89% paying interest) in the concession. The Manatee-1 well, .... [+ read more] which is located in shallow water in the prolific Niger Delta Basin, offshore Cameroon, was spud on 2 nd of March using the Paragon M825 jack-up rig, reached TD of 1,447 meters on 27 th of March. The well intersected 26 metres of gas bearing section of varying quality throughout the wellbore. Wellbore conditions did not permit the acquisition of a full suite of logging tools in the deeper sections of the hole which makes the analyses of these lower intervals inconclusive at this time. Additional technical work will be completed with the samples and material collected from the well to improve the understanding of their quality in a post well analyses. The operation was conducted safely and within the anticipated pre-well budget estimate.

25 Mar 2016

Steel Cutting Ceremony Held For R-550D AOD2 (H6006) Main Hull

On March 25, 2016, Alliance Offshore Drilling (AOD), a wholly owned subsidiary of TSC Group Holdings Limited (“TSC”) held a steel cutting ceremony for the second R-550D (H6006) jack-up drilling unit, AOD2 at CSSC Huangpu Wenchong Shipyard (“HPWS”) in Guangzhou, China. AOD and HPWS entered into a contract to construct the rig in June 2015, following the positive market response received .... [+ read more] for the first R-550D jack up rig, which recently completed its full jacking trial and is in the final phase of installation and commissioning at HPWS. Notably, a steel cutting ceremony for the R-550D AOD2 rig was held in October, 2015 followed by a keel laying ceremony in December, 2015.

23 Mar 2016

SDRL - Announces contract extension for West Tellus

Seadrill Limited ("SDRL" or "the Company") has been awarded an 18 month contract extension for the drillship West Tellus by Petroleo Brasileiro SA ("Petrobras"), commencing in April 2018 and securing work for the unit through the end of October 2019. The total backlog for the contract extension is approximately $164 million. As part of the agreement to extend the .... [+ read more] West Tellus, the Company has agreed to a dayrate reduction on the current contract effective from February 26th, 2016, resulting in a $132 million reduction in backlog. The net effect of this agreement is a $32 million increase in backlog.

21 Mar 2016

Atwood Oceanics Announces Program Changes for Australia Rigs

Atwood Oceanics, Inc. (NYSE: ATW) announced today that its Australia subsidiary's drilling services contract with Woodside Energy Ltd ("Woodside") for the semisubmersible Atwood Eagle has been suspended by mutual agreement effective March 19, 2016 and the remaining term of 165 days has been transferred to the semisubmersible Atwood Osprey for Woodside's utilization upon completion of the Atwood Osprey's current drilling program. .... [+ read more] The material contractual terms and conditions, including dayrate, of the Woodside drilling services contract remain unchanged after this assignment to the Atwood Osprey. The Atwood Eagle will temporarily remain in Australia until plans are finalized for its mobilization to Singapore, where the rig will be available for hire.

16 Mar 2016

Kosmos Energy Announces Successful Appraisal of Gas Discovery Offshore Mauritania and Senegal

Kosmos Energy (NYSE: KOS) announced today that its Ahmeyim-2 appraisal well has successfully delineated the Ahmeyim and Guembeul gas discoveries offshore Mauritania and Senegal. Located in Mauritanian waters, approximately 5 kilometers northwest, and 200 meters downdip of the basin-opening Tortue-1 discovery well in approximately 2,800 meters of water, Ahmeyim-2 was drilled to a total depth of 5,200 meters. As anticipated, .... [+ read more] in the Lower Cenomanian and Albian, Ahmeyim-2 penetrated the seismic-inferred gas-water contacts, defining the field limit and extending the productive field area from approximately 50 square kilometers to 90 square kilometers. Furthermore, the well confirmed significant thickening of the gross reservoir sequences down-structure and importantly, within the Lower Cenomanian, static fluid pressure communication between the Tortue-1, Guembeul-1 and Ahmeyim-2 wells. The well encountered 78 meters (256 feet) of net gas pay in two excellent quality reservoirs, including 46 meters (151 feet) in the Lower Cenomanian and 32 meters (105 feet) in the underlying Albian. These results demonstrate field-wide reservoir continuity and indicate Tortue West is a large, simple gas field. With the integration of the Ahmeyim-2 well results, our Pmean gross resource estimate for the Tortue West structure has increased to 15 Tcf from 11 Tcf as a result of extending the field area in the Cenomanian and the Albian. Accordingly, the Pmean gross resource estimate for the Greater Tortue Complex has increased to over 20 Tcf from 17 Tcf. “Ahmeyim-2 is our fourth successful exploration and appraisal well and continues our 100 percent success rate in the outboard Cretaceous petroleum system offshore Mauritania and Senegal, further demonstrating that Kosmos has opened a world-class hydrocarbon province. With this well, we believe we have proven sufficient gas resource to underpin a world-scale LNG project in the Tortue West structure alone. The combination of the resource size and quality continue to support our view that Tortue is a competitive source of LNG and we are working towards commercialization,” said Andrew G. Inglis, chairman and chief executive officer. “Our well-to-seismic calibration has again been proven, highlighting the reliability of this tool and increasing our confidence in its use for fully unlocking the basin, which we believe has significant potential for both oil and gas. We now plan to drill the first of three independent oil tests in our blocks offshore Mauritania and Senegal, starting with the Teranga-1 well, located in the Cayar Offshore Profond Block, offshore Senegal.” Since 2012, Kosmos has held rights to conduct exploration in the C-8, C-12, and C-13 contract areas under production sharing contracts with the Government of Mauritania’s Société Mauritanienne Des Hydrocarbures et de Patrimoine Minier (SMHPM). Kosmos operates the Ahmeyim-2 well with 90 percent equity and is joined by its partner SMHPM at 10 percent. The blocks are contiguous, range in water depth between 1,000 and 3,000 meters, and have combined acreage of approximately 27,000 square kilometers.

16 Mar 2016

Leiv Eiriksson contract to Westcon

Ocean Rig has signed a drilling contract with Lundin Norway for use of Leiv Eiriksson in the Barents Sea. After the completion of the contract with Rig Management Norway, the drilling rig has arrived at Westcon Yards in Olen. «We are very satisfied with winning this project in a demanding market situation. Westcon will prepare the rig for use in .... [+ read more] the Barents Sea. Among other things, this includes winterization and installation of third party equipment», says Malvin Eide, rig repair manager at Westcon. At the moment, the rig Polar Pioneer and Henry Goodridge are at the quays. Safe Scandinavia and Borgland Dolphin left Westcon Yards earlier this week. “We have thus good capacity and constantly looking for more projects», Eide says.

15 Mar 2016

BEL-1 well starts drilling offshore Senegal

Following the successful drilling of the first two appraisal wells offshore Senegal, the third well to be drilled as part of the SNE oil field appraisal program offshore Senegal has been spudded. The BEL-1 well will be drilled in approximately 1,100 metres of water and drilled to a TDVSS (total vertical depth subsea) of approximately 2,757 metres before an evaluation program .... [+ read more] including logging and coring is undertaken (refer figures 1 and 2). The aim of the appraisal program is to progress towards proving a minimum economic field size for the SNE discovery, which FAR estimates to be approximately 200 million barrels of oil. In addition, the BEL-1 well will drill the Bellatrix exploration prospect which will evaluate the untested Buried Hills play. BEL-1 will also be deepened to appraise the northern portion of the SNE oil field (refer figure 3). Drilling of the BEL-1 well will be followed by a wireline logging and coring program before the well is plugged and abandoned according to plans. BEL-1 operations are expected to be completed next month. FAR and its joint venture partners will be operating a tight hole policy, and therefore FAR does not anticipate making any further announcements regarding the drilling program until the BEL- 1 well has reached TDVSS.

14 Mar 2016

Consent to use West Epsilon for permanent well plugging

Statoil has received consent to use West Epsilon for permanent plugging of wells at Huldra 30/2-A, in production licence 051. Statoil has allocated 215 days for the activity, which will start in the second quarter of 2016. Water depth at the site is 125 metres. The PSA has now granted Statoil consent to use the West Epsilon mobile drilling facility .... [+ read more] for these activities. West Epsilon is operated by North Atlantic Drilling, formerly known as Seadrill Offshore AS. The Petroleum Safety Authority Norway issued an Acknowledgement of Compliance (AoC) for West Epsilon on 14 February 2003.

14 Mar 2016

Drilling permit for well 35/8-6 S in production licence 248

The Norwegian Petroleum Directorate (NPD) has granted Wintershall Norge AS a drilling permit for well 35/8-6 S, cf. Section 8 of the Resource Management Regulations. Well 35/8-6 S will be drilled from the Borgland Dolphin drilling facility in position 61°19’41.65” north and 3°20’17.11”east in production licence 248. The drilling programme for well 35/8-6 S relates to the drilling of a .... [+ read more] wildcat well. Wintershall is the operator with an ownership interest of 60 per cent. Petoro AS is a licensee with 40%. The area in this licence consists of part of block 35/8. Production licence 035 was awarded on 4 June 1999 (the North Sea Awards 1999). This is the fourth exploration well to be drilled within the area covered by the permit. The permit is contingent upon the operator having secured all other permits and consents required by other authorities before the drilling starts.

11 Mar 2016

Drilling permit for well 30/11-11 B in production licence 035

The Norwegian Petroleum Directorate has granted Statoil Petroleum AS a drilling permit for well 30/11-11 B, cf. Section 8 of the Resource Management Regulations. Well 30/11-11 B will be drilled from the Songa Delta drilling facility at position 60°4’29.77’’ north, 02°38’8.97’’ east in production licence 035. The drilling programme for the 30/11-11 B well relates to the drilling of a .... [+ read more] wildcat well. Statoil is the operator with an ownership interest of 50 per cent. Det norske oljeselskap ASA is a licensee, with an ownership interest of 50 per cent. The area in this licence consists of a part of block 30/11. Production licence 035 was awarded in licensing round 2-A on 14 November 1969. This is the eleventh exploration well to be drilled in the licence area. The permit is contingent upon the operator securing all other permits and consents required by other authorities before commencing drilling activities.

11 Mar 2016

Drilling permit for well 30/11-11 S in production licence 035

The Norwegian Petroleum Directorate has granted Statoil Petroleum AS a drilling permit for well 30/11-11 S, cf. Section 8 of the Resource Management Regulations. Well 30/11-11 S will be drilled from the Songa Delta drilling facility at position 60°4’29.77’’ north 02°38’8.97’’east in production licence 035. The drilling programme for the 30/11-11 S well relates to the drilling of a wildcat .... [+ read more] well. Statoil is the operator with an ownership interest of 50 per cent. Det norske oljeselskap ASA is a licensee with an ownership interest of 50 per cent. The area in this licence consists of a part of block 30/11. Production licence 035 was awarded in licensing round 2-A on 14 November 1969. This is the tenth exploration well to be drilled in the licence area. The permit is contingent upon the operator securing all other permits and consents required by other authorities before commencing the drilling activities.

10 Mar 2016

Drilling permit for well 16/1-26 S in production licence 001 B

The Norwegian Petroleum Directorate has granted Det norske oljeselskap AS a drilling permit for well 16/1-26 S, cf. Section 8 of the Resource Management Regulations. Well 16/1-26 S will be drilled from the Maersk Interceptor drilling facility at position 58°55’20.15’’ north, 02°11’53.03’’ east in production licence 001 B. The drilling programme for the 16/1-26 S well relates to the drilling .... [+ read more] of an appraisal well on the 16/1-7 oil discovery, which is part of the Ivar Aasen field where Det norske is the operator with an ownership interest of 34.7862 per cent. The other licensees are Statoil Petroleum AS with 41.4730 per cent, Bayerngas Norge AS with 12.3173 per cent, Wintershall Norske AS with 6.4615 per cent, VNG Norge AS with 3.0230 per cent, Lundin Norway AS with 1.3850 per cent and OMV (Norge) AS with 0.5540 per cent. The area in this licence consists of a part of block 16/1. The well was drilled in the eastern part of the 16/1-7 discovery in the central part of the North Sea. Production licence 001 B was carved out of production licence 001 on 1 September 1999. Production licence 001 was awarded on 1 September 1965 (Round 1-A). This is the eleventh exploration well to be drilled within the licence area and the fifteenth well on the Ivar Aasen field. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

9 Mar 2016

MSS1 to Invergordon

Semco Maritime has won a contract with Paragon Offshore for intermediate classification and service works on the SemiSub Drilling Rig Paragon MSS1. The service works will be performed at Semco Maritime’s rig facilities at Invergordon, Scotland, over an estimated period of 60 days. According to head of Semco Maritime Rig Projects, Senior Vice President Lars Skov, Semco Maritime was .... [+ read more] chosen due to its strategically located rig facilities at Invergordon, Hanøytangen (Norway) and Esbjerg (Denmark), together forming the North Sea rig triangle operated by Semco Maritime. “Our three strategically located hot spots in UK, Norway and Denmark offer the kind of flexibility, convenience and cost-efficiency that many of our rig clients are looking for in the current market”, says Lars Skov, while he first and foremost ascribes the order to Semco Maritime’s broad experience within rig service. Besides Invergordon, Semco Maritime rig facilities comprise yard facilities in Esbjerg (typically minor rig projects) as well as Hanøytangen, Norway, with an all-size dry dock and quay depths of more than 100 meters.

8 Mar 2016

Transocean Ltd. Announces High-Specification Jackup Delivery Delay

Transocean Ltd. (NYSE: RIG) (SIX: RIGN) announced today a mutual agreement with Keppel Offshore & Marine Ltd's shipyard, Keppel FELS, to defer the delivery and related payments of five high-specification jackups until 2020. The Super B 400 Bigfoot Class jackup drilling rigs are now scheduled to be delivered in two and three month intervals beginning in the first quarter of .... [+ read more] 2020.

8 Mar 2016

Transocean Ltd. Announces High-Specification Jackup Delivery Delay

Transocean Ltd. (NYSE: RIG) (SIX: RIGN) announced today a mutual agreement with Keppel Offshore & Marine Ltd's shipyard, Keppel FELS, to defer the delivery and related payments of five high-specification jackups until 2020. The Super B 400 Bigfoot Class jackup drilling rigs are now scheduled to be delivered in two and three month intervals beginning in the first quarter of .... [+ read more] 2020.

8 Mar 2016

Transocean Ltd. Announces High-Specification Jackup Delivery Delay

Transocean Ltd. (NYSE: RIG) (SIX: RIGN) announced today a mutual agreement with Keppel Offshore & Marine Ltd's shipyard, Keppel FELS, to defer the delivery and related payments of five high-specification jackups until 2020. The Super B 400 Bigfoot Class jackup drilling rigs are now scheduled to be delivered in two and three month intervals beginning in the first quarter of .... [+ read more] 2020.

8 Mar 2016

Transocean Ltd. Announces High-Specification Jackup Delivery Delay

Transocean Ltd. (NYSE: RIG) (SIX: RIGN) announced today a mutual agreement with Keppel Offshore & Marine Ltd's shipyard, Keppel FELS, to defer the delivery and related payments of five high-specification jackups until 2020. The Super B 400 Bigfoot Class jackup drilling rigs are now scheduled to be delivered in two and three month intervals beginning in the first quarter of .... [+ read more] 2020.

8 Mar 2016

Transocean Ltd. Announces High-Specification Jackup Delivery Delay

Transocean Ltd. (NYSE: RIG) (SIX: RIGN) announced today a mutual agreement with Keppel Offshore & Marine Ltd's shipyard, Keppel FELS, to defer the delivery and related payments of five high-specification jackups until 2020. The Super B 400 Bigfoot Class jackup drilling rigs are now scheduled to be delivered in two and three month intervals beginning in the first quarter of .... [+ read more] 2020.

7 Mar 2016

Dry well southwest of 16/4-6 S (Luno II) in the North Sea – 16/4-10

Lundin Norway AS, operator of production licence 544, is in the process of completing the drilling of wildcat well 16/4-10. The well is dry. The well is being drilled about 10 kilometres southwest of the 16/4-6 S (Luno II) oil discovery in the central part of the North Sea, 220 kilometres west of Stavanger. The objective of the well was .... [+ read more] to prove petroleum in Upper Jurassic reservoir rocks (the Ula formation). The well encountered about 160 metres of aquiferous sandstones in the Upper Jurassic to Middle Triassic, of which about 90 metres, mainly in the Middle Jurassic Sleipner formation, are of good reservoir quality. The well also encountered 75 metres of reservoir rocks with very good reservoir quality in the Paleocene Ty formation. There are traces of petroleum in the Sleipner formation. The well is classified as dry. Extensive data acquisition and sampling have been carried out. This is the second exploration well in production licence 544, which was awarded in APA 2009. Well 16/4-10 was drilled to a vertical depth of 2 638 metres below the sea surface, and was terminated in the Lower Triassic Smith Bank formation. Water depth at the site is 95 metres. The well will now be permanently plugged and abandoned. Well 16/4-10 was drilled by the Island Innovator drilling facility.

6 Mar 2016

Statoil terminating rig contract

Statoil has, on behalf of the Troll licence, decided to use its contractual right to terminate the contract with COSL Offshore Management AS for the chartering of the mobile rig COSLInnovator. “The conditions for terminating the contract signed with COSL Offshore Management AS have in our opinion been met, and we therefore choose to use our contractual right to terminate the .... [+ read more] contract,” says Geir Tungesvik, Statoil’s senior vice president for drilling and well. In addition Statoil has decided to stop drilling operation with the sister rig COSLPromoter when it is safe to discontinue well operations. This is done in order to enable COSL to implement the necessary actions in order to fulfil the requirements of the contract. The decision may have some short-term consequences for planned drilling activities, but will not have impacts on long-term production on the Troll field. The plans made by the licence for gas and fluid production from the oil zone remain firm.

3 Mar 2016

Lundin Petroleum completes Maligan exploration well, offshore Malaysia

Lundin Petroleum AB (Lundin Petroleum) announces that its wholly owned subsidiary Lundin Malaysia BV (Lundin Malaysia) has completed the Maligan exploration well in Block SB307/SB308, offshore East Malaysia. The Maligan well was drilled with the West Prospero jack-up rig to a total depth of approximately 1,380 metres and encountered significant gas shows. The well has now been plugged and abandoned and .... [+ read more] will be expensed in the first quarter of 2016. Lundin Malaysia holds 65 percent working interest in SB 307/308. Partners are DYAS B.V. with a 20 percent working interest and PETRONAS Carigali Sdn Bhd with a 15 percent working interest. Lundin Malaysia operates six blocks in Malaysia, namely PM307, PM319, PM308A, PM328, SB303 and SB307/308.

2 Mar 2016

Spudding of high impact exploration well on Bakassi West, Cameroon

– SDX Energy Inc. (“SDX” or the “Company”) (TSX VENTURE: SDX), an oil & gas exploration and production company with assets in Egypt & Cameroon, is pleased to announce that drilling operations have commenced on its high impact exploration well (Manatee-1) on Bakassi West, Cameroon. The well, which is located in shallow water in the prolific Niger Delta Basin, offshore Cameroon, .... [+ read more] will be drilled using Paragon M825 jack-up rig to a depth of 1,550 meters and the operation is expected to take up to 45 days. The well is operated by Dana Petroleum and SDX holds 35% working interest (38.89% paying interest) in the concession. The concession, which contains a number of discoveries, is covered by 350km of newly acquired 2D seismic from which 13 prospects and leads have been identified. The location of Manatee-1 is in the South Western corner of the block, and has been chosen based on the seismic data which has identified strong geological similarities to the adjacent Abana Field, which lies 7km’s to the Southwest. The Abana field has reported recoverable reserves of 85 MMBBL of high quality light crude oil which produced at a plateau rate of 30kbopd when it came on stream in 1999.

2 Mar 2016

Dry well northwest of the 7224/6-1 (Arenaria) gas discovery in the Barents Sea – 7224/2-1

Wintershall Norge AS, operator of production licence 611, is in the process of completing the drilling of wildcat well 7224/2-1. The well is dry. The well was drilled about 25 kilometres northwest of the 7224/6-1 (Arenaria) discovery and about 240 kilometres north of Hammerfest. The well's primary exploration target was to prove petroleum in Lower Triassic reservoir rocks (the Klappmyss .... [+ read more] formation). The secondary exploration target for the well was to prove petroleum in Upper Triassic reservoir rocks (the Snadd formation). Well 7224/2-1 did not encounter sandstones with reservoir quality in the Klappmyss formation, which nevertheless contains traces of petroleum. The well encountered two sandstone layers in the Snadd formation with thicknesses of about 45 and 15 metres and with very good reservoir quality. Both layers are aquiferous. The well encountered traces of petroleum in two thin sandstone layers in the Kobbe formation and in two thin sandstone layers with poor reservoir quality in the Havert formation. The well is classified as dry. Data acquisition has been carried out. This is the first exploration well in production licence 611. The licence was awarded on 13 May 2011 (21st licensing round). Well 7224/2-1 was drilled to a vertical depth of 2916 metres below sea the sea surface and was terminated in the Havert formation of Early Triassic age. The water depth at the site is 415 metres. The well will now be permanently plugged and abandoned. Well 7224/2-1 was drilled by the Transocean Arctic drilling facility.

2 Mar 2016

Dry well northeast of the Garantiana discovery in the North Sea - 34/6-4

Total E&P Norge AS, operator of production licence 554, is in the process of completing the drilling of wildcat well 34/6-4. The well is dry. The well was drilled about 6 kilometres northeast of the 34/6-2 S (Garantiana) oil discovery. The purpose of the well was to prove petroleum in Lower Jurassic reservoir rocks in the the Cook formation. .... [+ read more] The well encountered about 96 metres of aquiferous sandstone in the Cook formation with poor to moderate reservoir quality. The well is classified as dry. Data acquisition has been carried out. This is the fifth exploration well in production licence 554, awarded in 2010 (APA 2009). Well 34/6-4 was drilled to a vertical depth of 4084 metres below the sea surface and was terminated in the Lower Jurassic Burton Formation. Water depth in the area is 390 metres. The well will now be permanently plugged and abandoned. Well 34/6-4 was drilled by the Leiv Eriksson drilling facility.

1 Mar 2016

Update On Newbuild Jackup Noble Lloyd Noble

Noble Corporation plc (NYSE: NE) today reported its newbuild jackup rig, the Noble Lloyd Noble, sustained damage on February 28, 2016 following the collapse of a shipyard crane boom operating near the rig. The rig is in the late stages of construction at the Sembcorp Marine Jurong shipyard in Singapore. Damage appears to be confined to one area of the rig, .... [+ read more] including damage to one of the rig's cranes. The incident resulted in minor injuries to certain shipyard personnel. The Singapore Ministry of Manpower has commenced an investigation into the cause of the incident and access to the rig is limited during the initial phase of the investigation. Construction on the Noble Lloyd Noble was expected to be completed during the second quarter of 2016. Following mobilization of the rig to the North Sea, the rig was expected to commence a four-year primary term contract with Statoil during the third quarter of 2016, with the contract stipulating a commencement date of no later than March 1, 2017. A thorough rig damage assessment is required before a revised schedule of delivery and contract commencement can be determined.

1 Mar 2016

Production drilling started on Johan Sverdrup

At 00:00 on Tuesday 1 March the Deepsea Atlantic drilling rig commenced on the first of a total of 35 wells to be drilled in the first phase of the Johan Sverdrup field development. “The Deepsea Atlantic drilling rig is currently predrilling the first production well for the first phase of the Johan Sverdrup development. This is a central operation in .... [+ read more] a complex Johan Sverdrup puzzle. Predrilling allows the production capacity on the field to be utilised as efficiently as possible when Johan Sverdrup has come on stream late in 2019. This way, we maximize value from the field from day one,” says Kjetel Digre, senior vice president for the Johan Sverdrup project. The rig is drilling the first production well through a predrilling template that was installed on the field in the summer of 2015. A total of eight wells will be drilled through the predrilling template, before the rig is relocating to drill injection wells on three locations on the field. In 2018 the permanent Johan Sverdrup drilling platform will be installed as the second of four platforms. The drilling platform is currently being constructed at Aibel’s yard in Haugesund, north of Stavanger, and in Thailand. When the drilling platform is installed and operational, the eight predrilled wells will be hooked up from the predrilling template. At this point Deepsea Atlantic will be drilling the injection wells providing reservoir pressure support to maintain high field production. The operator Statoil, the rig owner Odfjell Drilling and the drilling service provider Baker Hughes have cooperated closely to ensure safe and cost-effective deliveries. The Johan Sverdrup project introduces integrated drilling services as a new concept, which means that Baker Hughes will provide the main deliveries together with Odfjell Drilling. “Statoil and the drilling service providers have worked as an integrated team in planning the drilling operation. Deepsea Atlantic is a good rig and everything is set for a safe and cost-effective drilling operation on Johan Sverdrup. This is vital to ensure production start from the field at the end of 2019,” says Digre. The contract for integrated drilling services worth NOK 1.5 billion was awarded to Baker Hughes on 6 July 2015. The contract for rig and drilling services on Johan Sverdrup, totalling more than NOK 4.35 billion, was awarded to Odfjell Drilling on 15 June 2015. Contracts worth more than NOK 50 billion have been awarded by the Johan Sverdrup project. More than 70% of them have been awarded to suppliers with a Norwegian billing address.

1 Mar 2016

Production drilling started on Johan Sverdrup

At 00:00 on Tuesday 1 March the Deepsea Atlantic drilling rig commenced on the first of a total of 35 wells to be drilled in the first phase of the Johan Sverdrup field development. “The Deepsea Atlantic drilling rig is currently predrilling the first production well for the first phase of the Johan Sverdrup development. This is a central operation in .... [+ read more] a complex Johan Sverdrup puzzle. Predrilling allows the production capacity on the field to be utilised as efficiently as possible when Johan Sverdrup has come on stream late in 2019. This way, we maximize value from the field from day one,” says Kjetel Digre, senior vice president for the Johan Sverdrup project. The rig is drilling the first production well through a predrilling template that was installed on the field in the summer of 2015. A total of eight wells will be drilled through the predrilling template, before the rig is relocating to drill injection wells on three locations on the field. In 2018 the permanent Johan Sverdrup drilling platform will be installed as the second of four platforms. The drilling platform is currently being constructed at Aibel’s yard in Haugesund, north of Stavanger, and in Thailand. When the drilling platform is installed and operational, the eight predrilled wells will be hooked up from the predrilling template. At this point Deepsea Atlantic will be drilling the injection wells providing reservoir pressure support to maintain high field production. The operator Statoil, the rig owner Odfjell Drilling and the drilling service provider Baker Hughes have cooperated closely to ensure safe and cost-effective deliveries. The Johan Sverdrup project introduces integrated drilling services as a new concept, which means that Baker Hughes will provide the main deliveries together with Odfjell Drilling. “Statoil and the drilling service providers have worked as an integrated team in planning the drilling operation. Deepsea Atlantic is a good rig and everything is set for a safe and cost-effective drilling operation on Johan Sverdrup. This is vital to ensure production start from the field at the end of 2019,” says Digre. The contract for integrated drilling services worth NOK 1.5 billion was awarded to Baker Hughes on 6 July 2015. The contract for rig and drilling services on Johan Sverdrup, totalling more than NOK 4.35 billion, was awarded to Odfjell Drilling on 15 June 2015. Contracts worth more than NOK 50 billion have been awarded by the Johan Sverdrup project. More than 70% of them have been awarded to suppliers with a Norwegian billing address.

29 Feb 2016

Operational Update for WilPhoenix

The WilPhoenix remains berthed at Hartlepool while awaiting final project acceptance by Apache North Sea Ltd prior to re-commencement of the remaining 22 months of its three-year contract. A further update will be released upon re-commencement of normal operations. WilPhoenix is one of Awilco Drilling's two enhanced pacesetter semi-submersibles and is equipped for drilling in water depths up to 1,200 .... [+ read more] ft.

29 Feb 2016

Island Innovator to Hanoytangen

Semco Maritime is to refurbish and service semisub rig Island Innovator when the rig arrives at Semco Maritime’s dock area at Hanøytangen, Bergen, in early March. Island Innovator is owned by Island Drilling and operated by Oddfjell Drilling, and the rig is constructed in 2012 and fitted with the latest in production equipment and state-of-the-art leisure and accommodation areas with .... [+ read more] one-man cabins for the 120 person crew. “The rig arrives at Hanøytangen from an assignment for Lundin Petroleum in the Norwegian part of the North Sea to undertake minor refurbishment and maintenance. Subsequently, the rig will be docked and operational at Hanøytangen until its next contract work commences,” explains Vice President Nikolaj Vejlgaard, Semco Maritime. “Hanøytangen’s facilities include both dock and dry dock, which are tailored for assignments such as this where a rig arrives for a brief stopover, a Special Periodic Survey or large-scale upgrade work before returning to operations,” says Nikolaj Vejlgaard. At the moment, the semisub rig West Venture is also docked at Hanøytangen, while Deep Sea Atlantic has recently left the facilities. The well-equipped dock facility at Hanøytangen comprises several dock areas, including a dry dock of 116x125 meters and quay areas with depths of at least 100 meters. The dockyard is fitted with modern equipment for repair and handling of rigs, rig gear and other very large elements on water and land, including crane capacity at all docking areas.

26 Feb 2016

Wintershall Norge AS receives consent for exploration drilling

Wintershall Norge AS (Wintershall) has received consent to drill two exploration wells, 35/8-6S and 35/8-6A, in the North Sea. Wintershall is the operator of production licence 248. Drilling is scheduled to begin in March 2016 and estimated to last 85 days, depending on whether a discovery is made. The wells will be drilled by Borgland Dolphin, which is a mobile drilling .... [+ read more] facility of the Aker H-3 type. It was built at Harland & Wolff in Belfast, Northern Ireland in 1977 and underwent an extensive upgrade in 1999. The facility is owned by Borgland Dolphin Pte Ltd and operated by Dolphin Drilling A/S. It received Acknowledgement of Compliance (AoC) in September 2004. The PSA has now granted Wintershall consent for exploration drilling.

25 Feb 2016

Minor gas discovery near the Oseberg field in the North Sea – 30/9-28 S

Statoil Petroleum AS, operator of production licence 104, has completed drilling of wildcat well 30/9-28 S. The well was drilled about 5.5 kilometres west of the Oseberg South field in the central part of the North Sea and 140 kilometres west of Bergen. The primary exploration target was to prove petroleum in Lower and Middle Jurassic reservoir rocks (the Tarbert .... [+ read more] formation and upper part of the Statfjord group). The secondary exploration target was to prove petroleum in Lower Jurassic reservoir rocks (lower part of the Statfjord group). The well encountered an approx. 20-metre gas column, of which 10 metres were in sandstone with good reservoir quality in the Tarbert formation. The gas/water contact in the Tarbert formation has been estimated at 2870 metres based on pressure data. In the Statfjord group, the well encountered a 12-metre gas column in sandstone with moderate reservoir quality. The gas/water contact was proven at 3506 metres. The secondary exploration target in the lower part of the Statfjord group is aquiferous. Preliminary estimation of the size of the discovery is between one and two million standard cubic metres (Sm3) of recoverable oil equivalents. The discovery will be considered for development as part of the “Oseberg Future Phase 2” project. The well was not formation-tested, but data acquisition and sampling were carried out. This is the 24th exploration well drilled in production licence 104. The well was drilled to a measured and vertical depth of 4083 and 3928 metres below the sea surface, respectively, and was terminated in the Statfjord group in the Lower Jurassic. Water depth is 99 metres. The well is now being permanently plugged and abandoned. Well 30/9-28 S was drilled by the Songa Delta drilling facility, which will now proceed to drill a shallow gas pilot, 30/6-U-27 in production licence 053, where Statoil Petroleum AS is the operator.

23 Feb 2016

Transocean Ltd. Receives Early Termination Notice on GSF Development Driller I

Transocean Ltd. (NYSE: RIG) (SIX: RIGN) announced today that the company has received a notice of early termination from Esso Exploration Angola (Block 15) Limited for the ultra-deepwater semisubmersible GSF Development Driller I. The rig's drilling contract is expected to end in May 2016 with the demobilization completed in June 2016. In accordance with the terms of this contract, the company .... [+ read more] will not receive a payment compensating it for the remaining contract term. The company does not have other contracts in its backlog that permit uncompensated cancellation for convenience.

19 Feb 2016

Vantage Drilling International Announces Agreement for Tungsten Explorer

Vantage Drilling International ("Vantage" or the "Company") announced today that it had signed an agreement for a two-year extension of the Tungsten Explorer contract. The contract is now anticipated to keep the Tungsten Explorer working until October 2018. Paul Bragg, President and Chief Executive Officer, commented, "We are pleased to announce this agreement with our customer. This agreement will provide .... [+ read more] visibility to cash flow for an extended period of time."

19 Feb 2016

Orca Exploration announces the completion of the offshore workover and drilling program phase of its Songo Songo Main Field development programme

Orca Exploration Group Inc announces the successful completion of its offshore workover and drilling program (the "Off-Shore Programme") and the release of the Paragon M826 mobile drilling workover rig. The Off-Shore Programme of the Songo Songo Main Field development programme (the "development programme") included workovers on three existing wells (SS-5, SS-7 and SS-9) and the drilling of one new development .... [+ read more] well, SS-12. Phase 1 of the development programme also includes the completion of the SS-12 production platform, flowlines and tie-in facilities connecting SS-12 to the Company's gas processing facilities and a refrigeration system required to ensure field production stability to enable the Company to produce wells into the newly built National Natural Gas Infrastructure Project ("NNGIP"). The total cost of Phase 1 of the development programme was originally estimated to cost US$120 million, however, now that the Off-Shore Programme has been completed, the Company expects that Phase 1 of the development programme to have a total cost of under US$80 million with costs incurred to date of approximately US$68 million. The reduction in costs was a result of being able to successfully workover the three wells without having to do any side-tracking, efficiencies achieved during the work-overs, and work scope changes which reduced the original estimated time required to complete Phase 1. The full development programme provides for additional workovers, compression systems and additional infrastructure to ensure all production commitments are met through to the end of the licence in 2026.

17 Feb 2016

Total E&P Norge A/S takes over jack-up Mærsk Gallant from Statoil

Statoil has cancelled the contract for the harsh environment jack-up rig Mærsk Gallant. A cancellation fee is due to Maersk Drilling, and will be handled in accordance with the contract. Concurrently, Maersk Drilling has signed a new contract with Total E&P Norge A/S for Mærsk Gallant in direct continuation of the cancelled contract. The contract cancellation and new contract will be .... [+ read more] financially neutral to Maersk Drilling. Mærsk Gallant has been on contract with Statoil since August 2014, and has since October 2015 been sub-chartered to ConocoPhillips. From February 2016 until August 2016, Mærsk Gallant will undertake the new contract with Total E&P Norge A/S.

16 Feb 2016

Construction deferred by 19 months

According to Ensco’s February 2016 fleet status report, the delivery of the Ensco 123 jackup has been deferred by 19 months, to the first quarter of 2018. .... [+ read more]

16 Feb 2016

Drilling commences at first well in the Gulf of Mexico

Otto Energy Ltd (ASX: OEL) (“Otto” or the “Company”) is pleased to announce that it has been advised by Operator, Byron Energy Inc., a subsidiary of Byron Energy Limited (ASX:BYE) (“Byron”), that the Hercules 205 drilling rig has commenced drilling (spud) the SM-6 #2 well located at the South Marsh Island Block 6 on 15 February 2016 at approximately 6pm (1800 .... [+ read more] hours) USA Central Time. Current operations at the SM-6 #2 well are drilling ahead at 146 metres/479 feet measured depth (146 metres/479 feet vertical depth). SM-6 #2 is being drilled in water depth of approximately 20 metres/65 feet, with a planned total measured depth of approximately 2,900 metres/9,516 feet and total vertical depth of 2,785 metres/9,138 feet. It is anticipated that the well will take approximately 40 days to drill and evaluate. The SM-6 #2 well is the first well to be drilled as part of Otto’s farm-in transaction with Byron announced in December 2015. The SMI-6 lease is part of a portfolio of low cost, high chance of success, conventional oil and gas opportunities located both onshore and offshore the Gulf of Mexico, which Otto has the option to participate in as part of the transaction. In order to earn a 50% working interest (equal to a 40.625% revenue interest) in the SMI-6 Lease, Otto will contribute 66.67% of the costs of the well (estimated at US$5.3 million net to Otto)). Any costs above this amount in respect of the SM-6 #2 well and all future expenditure on the license will be in accordance with Otto and Byron’s participating interest (Otto 50%).

15 Feb 2016

Termination of drilling contract

TOTAL E&P Congo on February 11, 2016 has given notification to terminate for convenience the long-term contract of the 7th generation ultra-deepwater drillship Ocean Rig Apollo. As per the contract Ocean Rig is entitled to a termination fee that varies from 50% to 95% of the operating daily rate that will be payable over the balance of the contract. The Ocean .... [+ read more] Rig Apollo will demobilize from Congo in due course and is available for alternative employment. In connection with the termination of the drilling contract of the Ocean Rig Apollo, the Company has notified the agent under the respective loan agreement and is currently in discussions with its lenders about the consequences of such termination.

12 Feb 2016

Termination of drilling contract

Premier and Noble Energy entered into a contract with Ocean Rig UDW (“Ocean Rig”) on 3 June 2014, for the provision of the Eirik Raude drilling unit for an exploration drilling campaign in the Falkland Islands. Following a number of material operational issues with the Eirik Raude rig during the term of the contract to date, Premier and Noble Energy .... [+ read more] issued a termination notice to Ocean Rig on 11 February 2016, terminating the contract with immediate effect. As a result, Premier will no longer be drilling the Chatham exploration well during the current campaign. However, we are in discussions with the Falkland Islands Government regarding the possibility of drilling this prospect in the future.

11 Feb 2016

Rig Mobilised for SM 6 #2 Well

Byron Energy Ltd (ASX: BYE) (“Byron” or the “Company”) is pleased to advise that the Hercules 205 drilling rig has been mobilised to the SM 6 #2 well location. The well is expected to spud about 6 days after rig mobilisation. Once on location, the rig will install new 30” conductor guides on the existing 72” caisson, drive 30” conductor pipe .... [+ read more] and then commence drilling the SM 6 #2 well. The SM6 #2 well is the first well to be drilled as part of Byron’s farm-out to Otto Energy Limited (“Otto”) (ASX:OEL), announced on 11 December 2015. In order to earn a 50% working interest (equal to a 40.625% net revenue interest) in the South Marsh Island block (“SM 6”), Otto will contribute 66.67% of the total estimated costs of the SM 6 #2 well of $US 8.0 million ($US5.3 million Otto and $US2.7 million Byron). Any costs above $US 8.0 million in respect of the SM 6 #2 well and all future expenditure in SM 6 will be in accordance with Byron’s and Otto’s respective working interest (Byron 50%/Otto 50%). SM 6 #2 will be drilled in water depth of approximately 65 feet (20 metres), with a planned total measured depth of approximately 9,516 feet (2,900 metres) and total vertical depth of 9,138 feet (2,785 metres). It is anticipated that the well will take approximately 40 days to drill and evaluate. The well will be drilled on a prospect in the south west corner of a major salt dome in SM 6, located offshore Louisiana, 216 km southwest of New Orleans, Louisiana, USA. The SM 6 #2 well will be drilled to only test the un-pressured (shallow) section of the South West Prospect. The primary target is the G 20 Sand, not penetrated by the SM 6 #1 BP 02 well drilled in mid-2014.

11 Feb 2016

Wilhunter SPS and Stacking

Timing of the planned WilHunter SPS will depend on when sufficient follow-on work is secured. The warm stack status on WilHunter is being continuously reviewed. .... [+ read more]

8 Feb 2016

Update on SM 6 #2 Well

Byron Energy Ltd (ASX: BYE) (“Byron” or the “Company”) advises that the contracted jack-up drilling rig, Hercules 205, has been released by the previous operator and is expected to commence mobilisation to the SM 6 #2 well in the South Marsh Island Block 6 (“SM 6”) when weather conditions allow. The current weather forecast indicates a possible weather window later this .... [+ read more] week. The day rate contract for the rig begins when the Hercules 205 is on location and ready to work. In anticipation of this move, Byron has opened a shore-base in Intracoastal City, Louisiana and has begun to mobilize equipment and supplies for load out to the rig once it is on location. The SM 6 #2 well is the first well to be drilled as part of Byron’s farm-out to Otto Energy Limited (“Otto”) (ASX:OEL), announced on 11 December 2015. The well will be drilled in the south west corner of a major salt dome in SM 6, located offshore Louisiana, 216 km southwest of New Orleans, Louisiana, USA. Byron, through its wholly owned subsidiary Byron Energy Inc. (the operator), currently has a 100% working interest and an 81.25% net revenue interest in SM 6. Otto will earn a 50% working interest in SM 6 by paying a disproportionate 66.67% share of drilling costs of the SM 6 #2 well, plus reimbursing a portion of Byron’s past costs. If Otto earns an interest in the SM 6 block, Byron’s working and net revenue interests will be reduced by 50% at the earn-in point, to 50% and 40.625% respectively. Byron will provide further information when the Hercules 205 rig commences mobilisation.

8 Feb 2016

Transocean Ltd. Announces Customer Early Terminates The Discoverer Deep Seas

Transocean Ltd. announced today that Murphy Exploration & Production Company - USA, a subsidiary of Murphy Oil Corporation, has elected to terminate the contract for the ultra-deepwater drillship Discoverer Deep Seas. The rig's contract was scheduled to end in November 2016. Transocean will be compensated for the early termination through a lump-sum payment that includes adjustments for operating costs. .... [+ read more]

8 Feb 2016

Maersk Developer to be Stacked

Following the completion of a six year long contract with Statoil, Mærsk Developer has now arrived for stacking just outside Port Fourchon, Louisiana, and will stay put until a new contract is in place. Unfortunately a new contract has not yet been secured for Mærsk Developer, which means that Maersk Drilling USA have had to say goodbye to 80 valued employees. .... [+ read more] "It goes without saying that I am very saddened by the fact that we had to say goodbye to so many good colleagues. I thank everyone for all of the great work they have done on board the Developer and as part of the rig team in Houston, and I wish them all the best in the future," says Lars Kasueske, Unit Director on Mærsk Developer.

8 Feb 2016

Drilling Commences on Baobab Marine-1 Well

SOCO, an international oil and gas exploration and production company, announces that the Baobab Marine-1 (“BABM-1”) commitment well commenced drilling on 5 February 2016 in the Mer Profonde Sud Block, located in the Lower Congo Basin, offshore the Republic of Congo. The BABM-1 well, to be drilled on the RR Prospect, is targeting stacked early Miocene channel complexes that are mappable .... [+ read more] in the seismic data, delineated by stratal discontinuities and variations in seismic amplitudes. Previous exploration drilling targeted different types of prospects, and the BABM-1 well is unique relative to all wells in and near the Block. Two wells on adjacent blocks along trend provide critical support to confirm that this wildcat tests an opportunity consistent with the known habitat of oil in the region. The BABM-1 well targets gross P50 prospective recoverable resource of c.330 million barrels of oil. The well will be drilled by the deepwater drillship Noble Globetrotter II and is expected to take 25 to 35 days, with a planned depth of approximately 3,400 metres below mean sea level. SOCO, with a 60% interest, is carrying 100% of the expected c.$25-30 million well cost.

5 Feb 2016

Consent to use Rowan Norway at Ekofisk 2/4 B

The PSA has granted ConocoPhillips consent to use the Rowan Norway mobile drilling facility for plugging and abandonment of wells at Ekofisk 2/4 B. Ekofisk is an oil field lying in 70-75 metres of water in the southern North Sea. The field was produced to tankers until a concrete storage tank was installed in 1973. Since then, the field has been .... [+ read more] further developed with many facilities, including riser facilities for associated fields and export pipelines. The operation is scheduled to start in February 2016. Rowan Norway is a jack-up drilling facility built in 2011 at Keppel Fels in Singapore. It is registered in Panama and classified by DnV GL. The facility received Acknowledgement of Compliance (AoC) on 21 December 2012. The PSA has now granted ConocoPhillips consent in accordance with the application.

4 Feb 2016

TSC’s First High Specification R-550D Jack-Up Rig Qualifies For Work In Indonesia

Recently, Alliance Offshore Drilling Pte Ltd.(“AOD”), a wholly owned subsidiary of TSC Group Holdings Limited (“TSC”), formally announced the “1+1” sales and purchase agreement with Harmoni Drilling Services Ltd (“HDS”) for the Zentech designed 400ft R-550D jack-up rig. An initial deposit has been received from HDS.The agreement with HDS replaces the sale to Petrolor previously announced on December 6th, 2013. .... [+ read more] The Rig is presently in the final stages of completion at the CSSC Huangpu Wenchong Shipbuilding Co Ltd (“HPWS”) shipyard in Guangzhou and will be well-primed for production in Indonesia by the second quarter of this year. The Rig has recently been successfully qualified and approved by the Directorate General of Sea Transportation and the Indonesian Classification Society - Biro Klasifikasi Indonesia. This paves the way for the Rig to be qualified for future operations in Indonesia at a competitive day-rate compared to non-Indonesian rigs.Through working with PT Harmoni Drilling Services, AOD is able to fulfill the mandatory local content factors required by the Indonesian Oil and Gas Authority, which is in line with the Indonesian Government pillar initiative of supporting growth of indigenous companies.

3 Feb 2016

Atlantica Delta arrived in Pointe Noire, Congo

January 30, 2016, the Atlantica Delta arrived in Pointe Noire, Congo to commence its contract with Total Congo on the Moho Nord development. .... [+ read more]

3 Feb 2016

Retirement of Noble Charles Copeland

In its fourth quarter results announcement, Noble Corporation announced its decision to retire the drillship Noble Discoverer and the jackup Noble Charles Copeland, thereby reducing its fleet count to 30 units. .... [+ read more]

3 Feb 2016

Retirement of Noble Discoverer

In its fourth quarter results announcement, Noble Corporation announced its decision to retire the drillship Noble Discoverer and the jackup Noble Charles Copeland, thereby reducing its fleet count to 30 units. .... [+ read more]

29 Jan 2016

Lundin Petroleum commences Maligan exploration well, offshore Malaysia

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that its wholly owned subsidiary Lundin Malaysia BV (Lundin Malaysia) has commenced drilling of the Maligan exploration well in Block SB307/SB308, offshore East Malaysia. The Maligan prospect is in shallow water and lies to the north of a major producing field in offshore East Malaysia. The well will target hydrocarbons in Miocene .... [+ read more] aged sands. Maligan will be drilled with the West Prospero jack-up rig to a total depth of approximately 1,700 metres below mean sea level. The drilling of the well is expected to take approximately 30 days. Lundin Malaysia holds 85 percent working interest in SB307/SB308. Partner is PETRONAS Carigali Sdn Bhd with 15 percent working interest. Lundin Malaysia operates six Blocks in Malaysia, namely PM307, PM319, PM308A, PM328, SB307/308 and SB303.

28 Jan 2016

Extension of Skipper Licence

Independent Oil and Gas plc ("IOG" or the "Company") (AIM: IOG.L), the North Sea focused oil and gas company, is pleased to announce that following discussions with the UK Oil & Gas Authority (“the OGA”), the Skipper Licence P1609 Block 9/21a has been formally extended until 31 December 2016. As previously indicated, IOG intends to drill the appraisal well as .... [+ read more] soon as economic conditions allow.

27 Jan 2016

Kosmos Energy Announces Significant Gas Discovery Offshore Senegal

Kosmos Energy (NYSE: KOS) announced today that its Guembeul-1 exploration well, located in the northern part of the St. Louis Offshore Profond license area in Senegal, has made a significant gas discovery. Located approximately five kilometers south of the basin-opening Tortue-1 gas discovery (renamed Ahmeyim) in approximately 2,700 meters of water, Guembeul-1 was drilled to a total depth of 5,245 .... [+ read more] meters. The well encountered 101 meters (331 feet) of net gas pay in two excellent quality reservoirs, including 56 meters (184 feet) in the Lower Cenomanian and 45 meters (148 feet) in the underlying Albian, with no water encountered. Importantly, Guembeul-1 has demonstrated reservoir continuity as well as static pressure communication with the Tortue-1 well in the Lower Cenomanian, suggesting a single, large gas accumulation. Moreover, the well has significantly de-risked adjacent prospectivity, including proving the existence of excellent quality reservoirs in the Albian. Furthermore, it has provided additional calibration of our seismic attribute exploration tool, confirming its reservoir and fluid predicative capability for these primary exploration targets. Based on the integration of the Guembeul-1 well results, our Pmean gross resource estimate for the Tortue West structure has increased to 11 Tcf from 8 Tcf as a result of greater reservoir (net to gross) confidence in the Cenomanian, as well as the inclusion of volumes in the Albian. Accordingly, the Pmean gross resource estimate for the Greater Tortue Complex has increased to 17 Tcf from 14 Tcf. Kosmos has also entered into a Memorandum of Understanding (MOU) signed by Pétroles du Sénégal (Petrosen) and Société Mauritanienne Des Hydrocarbures et de Patrimoine Minier (SMHPM), the national oil companies of Senegal and Mauritania, respectively, which sets out the principles for an intergovernmental cooperation agreement for the development of the cross-border Greater Tortue resource. The MOU enables Kosmos and the two governments to work together toward early development of the field, thereby maximizing value for all stakeholders. “We are pleased to have delivered another major discovery with our first exploration well offshore Senegal. Guembeul-1 confirms the presence of a world class gas resource that extends into both Senegal and Mauritania. With our successful appraisal program and support of both governments, the initial gas development is gaining momentum,” said Andrew G. Inglis, chairman and chief executive officer. “The Guembeul-1 well continues our 100% success rate in the outboard Cretaceous petroleum system offshore Senegal and Mauritania, which we believe is a strategically important new oil and gas province and we are focused on unlocking the basin’s full potential.” The Atwood Achiever drillship will now proceed to Mauritania to drill the Ahmeyim-2 delineation well in the southern part of Mauritania’s Block C-8. This will test the downdip limits of the field and is expected to complete appraisal of the Tortue West structure. Kosmos holds a 60 percent interest in the Guembeul-1 well, along with Timis Corporation Limited at 30 percent and Petrosen at 10 percent. Since 2014, Kosmos has held rights to conduct exploration in the St. Louis Offshore Profond and Cayar Offshore Profond license areas under production sharing contracts with the Government of Senegal.

25 Jan 2016

Keppel FELS delivers first rig of the year safely and on time

Keppel FELS, a wholly owned subsidiary of Keppel Offshore & Marine (Keppel O&M) has delivered Halul, a KFELS B Class jackup rig, to Gulf Drilling International Ltd. (q.s.c) (GDI) of Qatar. It was completed on 21 January 2016, ten days ahead of schedule, on budget and with a perfect safety record. It is the first rig that Keppel FELS has delivered .... [+ read more] this year. Halul is also the fifth KFELS B Class jackup rig delivered to GDI. With its continued successful partnership with Keppel FELS, GDI has renewed options for two more repeat KFELS B Class rigs for deliveries in 2018 and 2019. Mr Wong Kok Seng, Managing Director of Keppel O&M (Offshore) and Keppel FELS, said, "We are proud to deliver another rig to GDI early and safely. This is our first delivery of the year and we are proud that even in a low oil price environment, the KFELS B Class continues to be the preferred rig in the market for its high quality, efficiency and safety. "While there is widespread industry cautiousness, the strong relationships we have built with our long-standing customers, such as GDI, enables us to work together to deliver projects in a win-win fashion." The KFELS B Class rigs have a strong track record for GDI. Sister rigs Dukhan and Al Zubarah are operating successfully for Qatar Petroleum while Al Khor is performing well for Shell. Mr. Mubarak A. Al-Hajri, Chief Executive Officer and Managing Director of GDI, said, "We are pleased to receive the Halul ahead of schedule, enabling us to start work earlier for Qatar Petroleum. Reliability, safety, efficiency and quality are our top priorities in choosing a rig and a shipyard. Keppel FELS and the KFELS B Class design have demonstrated their strengths in these areas repeatedly. That is why we have chosen to renew our options for two more rigs with them. We are confident in the long term fundamentals of the industry and when the market recovers, we will be well-equipped to meet the demand." Built to GDI's requirements, the jackup rig has been designed to operate in the higher ambient temperature of the Middle East. The KFELS B Class is equipped with larger spud cans for reduced bearing pressure and expands its operational coverage in more places, especially in sea beds where soft soil is predominant. The rig can drill wells through 30,000 feet with a cantilever that can skid out 70 feet from the edge of the hull to drill wells. It features offline stand building capabilities and 7,500 PSI mud pumps, with accommodation for 150 persons. Besides newbuild rigs, Nakilat-Keppel O&M, Keppel's joint venture shipyard in Qatar, recently completed a self-propelled and self-elevating liftboat for GDI.

25 Jan 2016

Lundin Petroleum completes Bambazon exploration well, offshore Malaysia

Lundin Petroleum AB (Lundin Petroleum) announces that its wholly owned subsidiary Lundin Malaysia BV (Lundin Malaysia) has completed the Bambazon exploration well in Block SB307/SB308, offshore East Malaysia. The Bambazon well encountered approximately 15 metres of net logged reservoir pay with oil shows over three main reservoir intervals and the well has been plugged and abandoned and will be expensed in .... [+ read more] the first quarter of 2016. Bambazon was drilled with the West Prospero jack-up rig to a total depth of approximately 1,380 metres. Lundin Malaysia holds 85 percent working interest in SB 307/308. Partners are PETRONAS Carigali Sdn Bhd with a 15 percent working interest. Lundin Malaysia operates six blocks in Malaysia, namely PM307, PM319, PM308A, PM328, SB303 and SB307/308.

25 Jan 2016

Lundin Petroleum spuds exploration well on the Fosen prospect, offshore Norway

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that its wholly owned subsidiary Lundin Norway AS (Lundin Norway) has commenced drilling of exploration well 16/4-10 on the Fosen prospect. The well is located approximately 27 km south of the Edvard Grieg field and 11 km south of the Luno II discovery on the Utsira High on the Norwegian Continental Shelf .... [+ read more] (NCS). Well 16/4-10 will explore the Fosen prospect which is located on the southern flank of the Utsira High, west of the South Viking Graben in the North Sea. The main objective of the well is to test the hydrocarbon potential and reservoir properties at Jurassic sandstones level. The Fosen prospect is estimated to contain gross unrisked prospective resources of 192 MMboe. The planned total depth for the well is approximately 2,500 metres. The well will be drilled with the semisubmersible drilling unit Island Innovator and is expected to take approximately 50 days. Lundin Norway is the operator of PL544 with a 40 percent working interest. Partners are Lime Petroleum Norway AS with a 30 percent working interest and Bayerngas Norge with a 30 percent working interest.

21 Jan 2016

COSL Completed a High-quality Workover Integrated Operation with a Semi-submersible Rig

China Oilfield Services Limited (“COSL” or the “Company”), has smoothly completed its first workover integrated operation with a semi-submersible rig, NH5 of the Company, in South China Sea waters. There were huge challenges for this workover operation stemming from the swinging trunk of the semi-submersible rig due to the winter monsoon in South China Sea. Guided by excellent environmental protection concepts, .... [+ read more] NH5 developed appropriate measures and cooperated closely with the partners and tackled difficulties in precision positioning of the equipment and seamless matching of the operation procedures. NH5 completed this workover operation smoothly, thereby established a solid foundation for the timely resumption of production of the well for the client. With this outstanding operation, NH5 has not only helped COSL generate revenue, but also won full recognition and endorsement with relevant praise from the client.

21 Jan 2016

Ocean Rig announces notice of termination for the Ocean Rig Olympia

Ocean Rig, a global provider of offshore deepwater drilling services, announced today that “due to the dramatic fall of the crude oil price and the volatile market context, ENI has reassessed its drilling activities and taken the decision to exercise its right of terminating” the contract of the Ocean Rig Olympia. .... [+ read more]

20 Jan 2016

Dry well near the Njord field in the Norwegian Sea – 6407/10-4

Lundin Norge AS, operator of production licence 700 B, is in the process of completing the drilling of wildcat well 6407/10-4. The well is being drilled about 17 kilometres south-west of the Njord field in the Norwegian Sea. The primary exploration target for the well was to prove petroleum in Upper Jurassic reservoir rocks (the Rogn formation). The secondary exploration .... [+ read more] target was to prove petroleum in carbonate rocks from the Permian. The well did not encounter reservoir rocks in the primary or secondary exploration targets. However, the well did encounter about 830 metres of sandstones of unknown age, with poor to moderate reservoir quality. The reservoir rocks contain only traces of petroleum. The well is classified as dry. Extensive data acquisition and sampling have been carried out. This is the first exploration well in production licence 700 B. The licence was awarded in APA 2014. Well 6407/10-4 was drilled to a vertical depth of 3224 metres below the sea surface and was terminated in basement rock. Water depth at the site is 335 metres. The well will now be permanently plugged and abandoned. Well 6407/10-4 was drilled by the Island Innovator drilling facility, which will now drill wildcat well 16/4-10 in production licence 544 in the central part of the North Sea, where Lundin Norge AS is the operator.

19 Jan 2016

EDrill-2 Arrives at First Location

EDrill-2 departed COSCO Shipyard on 29th November after pre-mobilization inspections and third party equipment installation to arrive at the Gulf of Mottoma location on 21st December. The rig has safely and successfully completed it's mooring system field tests and heavy lifting operations with the DES set up on the first Zawtika wellhead platform. The first well’s top hole section has been .... [+ read more] drilled, cased and cemented. EDrill-2’s light-weight Drilling Equipment Set (DES) erects in four lifts and is handled by a large radius, 400MT crane which allows the tender barge to orient favorably in prevailing sea states and to minimize vessel motions for quick and safe rig moves. Zawtika Development Drilling Campaign (Phase 1B + Infield Phase 1A + Phase 1C) consists of around sixty-seven wells to be drilled from ten wellhead platforms in water depths of up to 160m.

18 Jan 2016

Deepsea Stavanger Awarded Drilling Contract with JX Nippon

JX Nippon Exploration and Production (U.K.) Limited (“JX Nippon”) has awarded Odfjell Drilling’s semi-submersible Deepsea Stavanger a contract for drilling one exploration well located West of Shetland on the UK Continental Shelf. “The contract with JX Nippon secures interim utilisation of Deepsea Stavanger before start up of the Wintershall drilling contract in 2017. We have a fleet of .... [+ read more] high performing rigs with a strong track record that gives us confidence in our market position even if the competition is tougher than ever. We look forward to demonstrating our capabilities for JX Nippon and its partners in the UK.” says Mr Simen Lieungh, CEO of Odfjell Drilling. Contract duration is estimated to be between 60 and 75 days and expected commencement is Q2 2016. Deepsea Stavanger finalised its contract with BP in Angola in November 2015 and has thereafter completed its 5-year special periodic survey. The rig is now underway to Norway before mobilising to UK waters for start-up on the JX Nippon contract. Deepsea Stavanger has a contract with Wintershall on the Maria field on the Norwegian Continental Shelf starting early 2017.

18 Jan 2016

Dry well west of the Balder field in the North Sea – 25/10-14 S

Suncor Energy Norge AS, operator of production licence 571, has completed the drilling of wildcat well 25/10-14 S. The well was drilled in the central part of the North Sea, about five kilometres west of the Balder field and about 200 kilometres north-west of Stavanger. The primary exploration target for the well was to prove petroleum in Paleocene reservoir rocks .... [+ read more] (the Ty formation). The secondary exploration target was to prove petroleum in Lower Jurassic reservoir rocks (the Statfjord group). The well encountered a 22-metre thick sandstone layer in the Ty formation and 63 metres of sandstone in the Statfjord group, both of which showed good reservoir properties. The well is dry. Well 25/10-14 S was drilled to a measured depth of 2474 metres and a vertical depth of 2374 metres below the sea surface, and was terminated in the Triassic (the Hegre group). This is the second exploration well in production licence 571. The licence was awarded in APA 2010. Water depth at the site is 119 metres. The well will now be permanently plugged and abandoned. The well was drilled using the Borgland Dolphin drilling facility.

15 Jan 2016

SDRL - Announces Agreement with DSME Shipyard

Seadrill Limited ("SDRL" or "the Company") announces today that an agreement with DSME shipyard has been reached to defer the delivery of two ultra-deepwater drillships, the West Aquila and West Libra, until the second quarter of 2018 and first quarter of 2019 respectively. Under the terms of the original construction contracts, the units were to be delivered by the end .... [+ read more] of the second quarter of 2016 and the total final yard instalment for both units of over $800 million was due at that time. This agreement significantly improves the Company's near term liquidity position by deferring these capex commitments to 2018 and 2019 with no further payments to the yard until that time.

15 Jan 2016

SDRL - Announces Agreement with DSME Shipyard

Seadrill Limited ("SDRL" or "the Company") announces today that an agreement with DSME shipyard has been reached to defer the delivery of two ultra-deepwater drillships, the West Aquila and West Libra, until the second quarter of 2018 and first quarter of 2019 respectively. Under the terms of the original construction contracts, the units were to be delivered by the end .... [+ read more] of the second quarter of 2016 and the total final yard instalment for both units of over $800 million was due at that time. This agreement significantly improves the Company's near term liquidity position by deferring these capex commitments to 2018 and 2019 with no further payments to the yard until that time.

14 Jan 2016

Update on Contract for the Provision of Tender Assist Drilling Rig "SKD T-20"

Reference is made to the Company’s previous announcement, dated 15 May 2014, for SapuraKencana Drilling Holdings Ltd’s Tender Assist Drilling Rig SKD T-20 (“SKD T-20”) offshore Côte d'Ivoire. The contract is now expected to be completed in June of 2016, adding to the original contract term. Additionally, there is the option to extend the contract by 5 additional wells, which .... [+ read more] if exercised, will keep the SKD T-20 on contract to the final quarter of 2016.

14 Jan 2016

Contract for SKD Esperanza

SapuraKencana Drilling Tioman Sdn. Bhd. has been awarded a contract from Sarawak Shell Berhad (“SSB”)/ Sabah Shell Petroleum Co. Ltd (“SSPC”) for the provision of its Semi Tender Assist Drilling Rig “SKD Esperanza”. The contract is for the nominal term of 18 months with options to extend for up to a further 18 months. .... [+ read more]

14 Jan 2016

Consent for exploration drilling

Total E&P (Total) is the operator for production licence 618 and has received consent to drill exploration well 1/5-5 using Mærsk Gallant. Mærsk Gallant is a jack-up drilling facility, built at Far East Levingston Shipbuilding (FELS) in Singapore in 1993. The facility is operated by Maersk Contractors Norge A/S. It received Acknowledgement of Compliance (AoC) in August 2002. The Petroleum .... [+ read more] Safety Authority Norway has now granted consent for the use of Maersk Gallant in accordance with Total's application.

13 Jan 2016

Stena Carron Contract with Esso

Stena Carron Drilling Limited (UK Company) has been awarded a drilling contract by Esso Exploration and Production Guyana Limited (Guyana Company) for Stena Carron. The contract is for a period of one year at $235 000/day plus 1 priced six month option with further options to be agreed at market rate. The unit has started mobilization to location and plan commencement .... [+ read more] end of January 2016.

12 Jan 2016

Rescheduling of Skipper Well

Following recent oil price movements and bad weather in the North Sea, IOG believes that it is in the best interests of shareholders that the Skipper appraisal well is delayed until there is greater stability and clarity in the oil market. The existing timetable for drilling Skipper in Q1 2016 requires the announced loans and contractor deferral funding to be .... [+ read more] repaid by IOG at the end of 2016. IOG now considers this refinancing risk to be increased due to the very weak commodity prices and negative market sentiment towards oil and gas. Moreover, the very bad weather in the North Sea has increased concerns that significant delays could be encountered or a sub-optimal well result may be achieved. Therefore, the Board believes that drilling in a more favourable weather window with at least some improvement in market sentiment would be prudent. The Company now anticipates the Skipper appraisal well to be drilled later this year. To achieve this revised timetable, IOG will need agreement from its principal lenders and contractors and agreement from the OGA to extend the Skipper licence beyond 30 March 2016. These critical discussions are ongoing.

8 Jan 2016

Consent for drilling operations using Transocean Winner

Det norske oljeselskap ASA has received consent to use the Transocean Winner mobile drilling facility for production drilling and completion on the Volund field. ransocean Winner is a semi-submersible facility of the GVA 4000 type, built at Gøtaverken Arendal in Gothenburg in 1983 and significantly upgraded in 2006. The facility is owned and operated by Transocean Ltd, registered in the Marshall .... [+ read more] Islands and classified by DNV GL. Transocean Winner was issued with an Acknowledgement of Compliance (AoC) by the PSA in August 2006. Volund is an oil field in the central North Sea around 10 kilometres south of the Alvheim field. Water depth in the area is 120-130 metres. The field has been developed using a subsea facility tied back to the Alvheim FPSO production vessel, with three horizontal wells. The Petroleum Safety Authority Norway has now granted Det norske oljeselskap ASA consent for drilling operations in compliance with the company's application.

8 Jan 2016

Lundin Petroleum completes Imbok exploration well, offshore Malaysia

Lundin Petroleum AB (Lundin Petroleum) announces that its wholly owned subsidiary Lundin Malaysia BV (Lundin Malaysia) has completed the Imbok-1 exploration well in Block SB307/308, offshore East Malaysia. The well encountered minor oil shows and was plugged and abandoned. The well was targeting hydrocarbons in Miocene aged sands. Imbok-1 was drilled with the West Prospero jackup rig. Lundin Malaysia holds 85 .... [+ read more] percent working interest in SB307/308. Partner is PETRONAS Carigali Sdn Bhd with a 15 percent working interest. Lundin Malaysia operates six Blocks in Malaysia, namely PM307, PM319, PM308A, PM328, SB303 and SB307/308.

8 Jan 2016

Lundin Petroleum commences Bambazon exploration well, offshore Malaysia

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that its wholly owned subsidiary Lundin Malaysia BV (Lundin Malaysia) has commenced drilling of the Bambazon exploration well in Block SB307/SB308, offshore East Malaysia. The Bambazon prospect is in shallow water and lies to the north of a major producing field in offshore East Malaysia. The well will target hydrocarbons in Miocene .... [+ read more] aged sands. Bambazon will be drilled with the West Prospero jack-up rig to a total depth of approximately 1,250 metres below mean sea level. The drilling of the well is expected to take approximately 25 days. Lundin Malaysia holds 85 percent working interest in SB307/SB308. Partner is PETRONAS Carigali Sdn Bhd with a 15 percent working interest. Lundin Malaysia operates six Blocks in Malaysia, namely PM307, PM319, PM308A, PM328, SB307/308 and SB303.

8 Jan 2016

Acknowledgement of Compliance for Songa Endurance

Songa Offshore has received the PSA's Acknowledgement of Compliance (AoC) for Songa Endurance. Songa Endurance is a semi-submersible drilling facility and the first of four Cat D rigs that Songa is building for Statoil. In total, 59 mobile facilities have now received an Acknowledgement of Compliance from the PSA. .... [+ read more]

5 Jan 2016

Statoil receives consent for exploration drilling in the North Sea

Statoil is the operator for production licences 272 and 035 and has received consent to drill exploration well 30/11-11 using Songa Delta. Statoil has allocated 36 days for the activity, which will start in mid-January 2016. The well is located around 28 kilometres south of the Oseberg field, and around 130 kilometres from the nearest land at Sund municipality in .... [+ read more] Hordaland county. Water depth at the site is around 106 metres. Songa Delta is operated by Songa Offshore. The facility was issued with an Acknowledgement of Compliance (AoC) by the PSA in November 2012. The PSA has now granted Statoil consent for exploration drilling.

4 Jan 2016

Woodside Discovers Gas Offshore Myanmar

Woodside advises that the Shwe Yee Htun-1 exploration well in Block A-6 in the Rakhine Basin, located in the western offshore area of Myanmar, has intersected a gross gas column of approximately 129 m. Approximately 15 m of net gas pay is interpreted within the primary target interval. The well reached the planned original total depth (TD) of 4810 m, referenced .... [+ read more] from the rig rotary table. Following drilling, wireline logging was conducted and confirmed the presence of a gas column through pressure measurements and gas sampling. The well was subsequently deepened to a final TD of 5306 m. The well was spudded on 27 November, reached its original target on 23 December and wireline logging concluded on 29 December. Shwe Yee Htun-1, in Block A-6, targeted one of many identified channel complexes that run over a large anticlinal feature, the Saung Anticline. Woodside CEO Peter Coleman said he was pleased by the successful evaluation of the prospect, which provided evidence of a working petroleum system in the Rakhine Basin deep water. “Further analysis will be undertaken to understand the full potential of the play, but this de-risks a number of leads which will now be matured,” Mr Coleman said. “This discovery is an encouraging outcome for future exploration and appraisal activity in the area.” With a 40% interest in A-6, Woodside Energy (Myanmar) Pte Ltd (Woodside Myanmar) is the joint operator with MPRL E&P Pte Ltd (MPRL E&P) (20% interest). MPRL E&P is operator with respect to government liaison and Woodside Myanmar is the operator with respect to all other operations, including drilling. Total E&P Myanmar holds a 40%, non-operated interest. Woodside has interests in six blocks in the Rakhine Basin (details overleaf). The six permits make up 46,000 km2 and represent 20% of Woodside’s global exploration acreage.

4 Jan 2016

Successful Senegal Appraisal Well

Cairn is pleased to announce the successful testing of the SNE-2 appraisal well offshore Senegal with positive results. Operations have been safely and successfully completed following drilling, coring, logging and drill-stem testing (DST). The well is now being plugged and abandoned. Following this first successful appraisal well, resource estimates for the SNE field will be fully revised and announced after .... [+ read more] the results of the further appraisal activity. Evaluation of the extensive dataset collected is continuing, with preliminary analysis focused on the DST. The SNE- 2 well is located in 1,200m water depth and is approximately 100 kilometres (km) offshore in the Sangomar Offshore block, reached the planned total depth (TD) of 2,800m below sea level (TVDSS). The well has been appraising the 2014 discovery of high quality oil in the SNE-1 well, some 3 km to the south.

31 Dec 2015

Songa Endurance commencement of drilling contract

Songa Endurance has today commenced drilling operations under its eight-year drilling contract with Statoil at the Troll Field on the Norwegian continental shelf, and the rig is now on operating rate. Songa Endurance is the second rig in a series of four Category D semi-submersible drilling rigs, specifically built for and contracted to Statoil. .... [+ read more]

31 Dec 2015

Minor gas discovery on the Finnmark platform in the Barents Sea – 7130/4-1

Lundin Norge AS, operator of production licence 708, is in the process of concluding the drilling of wildcat well 7130/4-1. The well is being drilled about 85 kilometres north-east of Berlevåg. The primary exploration target for the well was to prove petroleum in carbonate and spiculite reservoir rocks (the Røye formation) in the Upper Permian. The secondary exploration target was to .... [+ read more] prove petroleum in underlying carbonates and sandstones (the Ørn formation and the Soldogg formation) in the Permian and Carboniferous Ages. In the primary exploration target, well 7130/4-1 encountered an approx. 40 metre thick aquiferous spiculite reservoir in the Røye formation, with poor reservoir quality. In the secondary exploration target, the well proved traces of petroleum in the Ørn formation. The formation is about 180 metres thick, but is mainly tight. In the Soldogg formation, the well encountered a 5 metre thick gas column in a sandstone reservoir with moderate reservoir quality. In total, the well encountered about 85 metres of reservoir in the Soldogg formation. The gas/water contact was encountered. The assessment of the size of the discovery is unclear at this time, but indications are that it is too small to be commercial. The well was not formation-tested, but extensive data acquisition and sampling have been carried out, with cores from the primary exploration target, and lateral cores in the secondary exploration target (the Soldogg formation). This is the first exploration well in production licence 708. The licence was awarded in the 22nd licensing round in 2013. Well 7130/4-1 was drilled to a vertical depth of 3184 metres below the sea surface and was terminated in the Soldogg formation in the Lower Carboniferous. Water depth at the site is 288 metres. The well will now be permanently plugged and abandoned. Well 7130/4-1 was drilled by the Transocean Arctic, which will now drill wildcat well 7224/2-1 in production licence 611 in the Barents Sea, where Wintershall Norge AS is the operator.

30 Dec 2015

Fatality on board COSL rig

It is with great sadness that Statoil and COSL have received confirmed information from the police that one person has died as a result of the breaking wave that hit the drilling rig COSL Innovator today. Two other people were injured and are receiving medical treatment ashore. The rig is now heading to shore under its own power, while evacuation takes .... [+ read more] place. COSL and Statoil were notified at 5 pm on Wednesday 30 December that three people had been injured when a breaking wave hit COSL Innovator. Statoil and COSL have mobilized their emergency response organizations. COSL Innovator is under contract to Statoil at the Troll field in the North Sea, west of Bergen. The rig had been taken off the well as a result of the bad weather before the incident occurred. The breaking wave also caused some damage to the rig's accommodation module. The injured persons have been flown to shore by Sea King helicopter from the Joint Rescue Coordination Centre and by one of Statoil’s own rescue helicopters. Statoil is assisting COSL with evacuation of the rig down to the safety crew. Evacuees are being flown ashore.

28 Dec 2015

Transocean Ltd. Announces Customer Early Termination of Polar Pioneer Contract

Transocean Ltd. announced today that Shell has elected to terminate the contract for the harsh environment semisubmersible Polar Pioneer prior to its expiration in July 2017. Transocean will be compensated for the early termination through a lump-sum payment that includes adjustments for reduced operating costs and demobilization to Norway. .... [+ read more]

23 Dec 2015

Delineation of the 16/1-12 oil discovery (Edvard Grieg South) in the North Sea - 16/1-25 S

Lundin Norway AS, operator of production licence 338 C, has completed the drilling of exploration well 16/1-25 S. The well was initially classified as a wildcat well, but will now be reclassified as an appraisal well. The well was drilled about six kilometres south of the Edvard Grieg field in the central part of the North Sea, about three kilometres .... [+ read more] south of the 16/1-12 discovery, 190 km west of Stavanger. The discovery was proven in basement rocks in 2009. After drilling the discovery well, the operator's resource estimate for the discovery was between three and eight million standard cubic metres (Sm3) of recoverable oil. The objective of the well was to prove oil in thin sandstone layers in Upper Jurassic / Lower Cretaceous reservoir rocks, and in the underlying jointed, porous granitic basement rock. Upper Jurassic/Lower Cretaceous reservoir rocks were not present. The well encountered an oil column of about 30 metres in jointed, porous basement rock, with reservoir quality varying from poor to moderate, depending on the degree of fracturing. The oil/water contact was encountered at 1927 metres below the sea surface. Collected pressure data shows communication with the 16/1-12 oil discovery, with approximately the same oil/water contact. Preliminary estimates place the size of the discovery between two and seven million Sm3 of recoverable oil. The licensees will assess the discovery with a view towards a tie-in to the Edvard Grieg field. Extensive data acquisition and sampling have been carried out. Several formation tests (a DST, 5 mini-DSTs and a fracture/injection test) have been conducted. The production rate from DST was 42 Sm3 of oil per flow day through a 36/64-inch nozzle opening. The oil is under-saturated with a gas/oil ratio of 180 Sm3/Sm3. The formation tests (DST and mini-DST) mainly revealed moderate production and flow properties. Due to poor communication from the well to the porous, fractured basement rock, paraffin was injected in a minor fracturing and injection test, which yielded stable rates of 1000 Sm3 per day. This is the second exploration well to be drilled in production licence 338 C, which was carved out of production licence 338 and awarded on 16 December 2014. Well 16/1-25 S was drilled to respective vertical and measured depths of 2096 and 2185 metres below the sea surface, and was terminated in granitic basement rock. The well will be permanently plugged and abandoned. Water depth at the site is 106 metres. The well was drilled by the Bredford Dolphin drilling facility.

22 Dec 2015

Oil discovery in the Rolvsnes prospect, offshore Norway

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that its wholly owned subsidiary Lundin Norway AS (Lundin Norway) has completed the Rolvsnes exploration well 16/1-25 S as an oil discovery. The well is located in PL338C south of the Edvard Grieg field in the central North Sea sector of the Norwegian Continental Shelf (NCS). The well is located on the .... [+ read more] southwestern flank of the Utsira High, approximately 6 km south of the Lundin Petroleum operated Edvard Grieg field and 3 km south of the Edvard Grieg South discovery. The well encountered a gross oil column of 30 metres in porous granitic basement. Pressure data and oil type indicate that the petroleum system is in communication with the Edvard Grieg South discovery which was made by Lundin Norway in 2009. Extensive data acquisition and sampling was carried out in the reservoir including conventional coring and fluid sampling. A production test (DST) was performed, achieving a production rate of 265 barrels of oil per day through a 36/64” choke. Further studies will be required to incorporate all the findings and establish future planning, such as the potential drilling of an extended reach well from the Edvard Grieg platform with an associated longterm production test. The gross contingent resource range for Rolvsnes, based on natural depletion drive, including the Edvard Grieg South discovery is estimated to be between 3 and 16 million barrels of oil equivalents (MMboe). There remains significant resource upside including potential to find a more extensive fracture network and secondary recovery potential. Including this prospective upside potential the total gross resource estimate is between 10 and 46 MMboe. Exploration well 16/1-25 S is the second well drilled in PL 338C, which was carved out from PL338 in late 2014. Well 16/1-25 S was drilled to a total depth of 2,096 metres below mean sea level in a water depth of 106 metres. The well was drilled using the semi-submersible drilling rig Bredford Dolphin and will be permanently plugged and abandoned. Lundin Norway is the operator of PL338C with 50 percent working interest. The partners are Lime Petroleum Norway with a 30 percent working interest and OMV (Norge) AS with 20 percent working interest.

22 Dec 2015

Drilling permit for well 7324/7-3 S in production licence 537

The Norwegian Petroleum Directorate (NPD) has issued a drilling permit to OMV Norge AS for well 7324/7-3 S, cf. Section 8 of the Resource Management Regulations. Well 7324/7-3 S will be drilled from the Transocean Spitsbergen drilling facility in position 73o26`30.78" north and 24o15´39.88" east. The drilling programme for well 7324/7-3 S relates to the drilling of an appraisal well .... [+ read more] in production licence 537. OMV Norge AS is the operator with a 25 per cent ownership interest. The other licensees are Idemitsu Petroleum Norge AS with 20 per cent, Petoro AS with 20 per cent, Tullow Oil Norge AS with 20 per cent and Statoil Petroleum AS with 15 per cent. The production licence comprises blocks 7324/7 and 7324/8, and was awarded in the 20th licensing round in 2009. Wildcat well 7324/7-3 S will be the fifth exploration well in production licence 537. The permit is conditional upon the operator securing all other consents and permits required by other authorities prior to commencing the drilling activity.

22 Dec 2015

Oro Negro Signs Charter Agreement and Contract Extensions with PEMEX

On December 21, 2015, Perforadora Oro Negro, S. de R.L. de C.V. (“Oro Negro”) and Pemex Perforación y Servicios, ENS (“Pemex”) executed a new charter agreement for Oro Negro´s Impetus rig, for a period of 5 years with a day rate of USD$130,000.00. In addition, Oro Negro and Pemex Exploración y Producción signed amendments to the outstanding charter leases for Oro .... [+ read more] Negro’s rigs Primus, Laurus, and Fortius. The amendments provide a one year extension on the term on the contracts for each of the above mentioned rigs. Oro Negro expects to sign a similar one year extension for the Decus rig in the near term.

21 Dec 2015

Drilling permit for well 7224/2-1 in production licence 611

he Norwegian Petroleum Directorate (NPD) has granted Wintershall Norway AS a drilling permit for wellbore 7224/2-1, cf. Section 8 of the Resource Management Regulations. Well 7224/2-1 will be drilled from the Transocean Arctic drilling facility at position 72°46’25.92" north and 24°23’56.33" east following completion of drilling of wildcat well 7130/4-1 for Lundin Norway AS in production licence 708. The drilling .... [+ read more] program for well 7224/2-1 concerns the drilling of a wildcat well in production licence 611. Wintershall Norge AS is the operator with an ownership interest of 40 per cent. The other licensees are Faroe Petroleum Norge AS (40 per cent) and Petoro AS (20 per cent). The area in this licence is comprised of the blocks 7223/3, 7223/6, 7224/1, 7224/2, 7224/3, 7224/4 and 7224/5. The well is being drilled about 25 kilometres northwest of the discovery 7224/6-1 (Arenaria) and about 240 kilometres north of Hammerfest. Production licence 611 was awarded on 13 May 2011 (21st licensing round). This is the first well to be drilled in the licence. The permit is contingent upon the operator having secured all other permits and consents required by other authorities prior to commencing the drilling activity.

21 Dec 2015

Completion of Physical Build of Explorer 1

Amedeo is pleased to announce that the physical build of Jiangsu Yangzijiang Offshore Engineering Co. Ltd's ("YZJ Offshore") first rig order, the Le Tourneau Super 116E Class design self-elevating mobile offshore jack up drilling rig, Explorer 1, has been completed. Testing, including to American Bureau of Shipping classifications, and commissioning, which constitute a key part of the delivery package, have .... [+ read more] already commenced and are expected to be completed during 2016. Glen Lau, Chief Executive Officer, commented: "We are pleased that physical build of YZJ Offshore's first rig is complete. Following successful testing and commissioning, the rig will be delivered to the client. The physical completion of the first build is a key milestone from several perspectives, including in establishing the good reputation of a yard."

21 Dec 2015

KCA Deutag Disposal of Ben Loyal Jack-Up Drilling Unit

Leading global drilling and engineering contractor, KCA Deutag, today announces that it has sold its jack-up drilling unit, the Ben Loyal to Egyptian headquartered Advanced Energy Systems A.D.E.S. SAE for an undisclosed sum. Built in 1981 and acquired by KCA Deutag in 2005, the Ben Loyal's operational performance has been strong and until October of this year it had .... [+ read more] been continuously under contract in the Gulf of Mexico. The Friede & Goldman L-780 MOD II rig, which is due for a special periodic survey next year, is capable of drilling in water depths of 300ft. Norrie McKay, KCA Deutag CEO said: "The sale of the Ben Loyal is another important step for KCA Deutag as we continue to focus our growth strategy on our core businesses of premium rig services, specialist engineering and design, and land rig manufacturing."

18 Dec 2015

Atwood Oceanics announces changes to delivery schedules for two ultra-deep water drillships

Atwood Oceanics, Inc. (NYSE: ATW) announced today that subsidiaries of the Company have agreed with Daewoo Shipbuilding & Marine Engineering Co. (DSME) to delay the Company's requirement to take delivery of two newbuild ultra-deepwater drillships, the Atwood Admiral and the Atwood Archer, to September 30, 2017 and June 30, 2018, respectively. In consideration of the agreement, the .... [+ read more] Company will make payments of $50 million for each drillship on December 31, 2015, and DSME will extend all remaining milestone payments, $93.9 million for the Admiral and $305 million for the Archer, until their respective delivery dates. The Company retains the option to take earlier delivery of each vessel, subject to a forty-five (45) day notice period to DSME.

18 Dec 2015

Atwood Oceanics announces changes to delivery schedules for two ultra-deep water drillships

Atwood Oceanics, Inc. (NYSE: ATW) announced today that subsidiaries of the Company have agreed with Daewoo Shipbuilding & Marine Engineering Co. (DSME) to delay the Company's requirement to take delivery of two newbuild ultra-deepwater drillships, the Atwood Admiral and the Atwood Archer, to September 30, 2017 and June 30, 2018, respectively. In consideration of the agreement, the .... [+ read more] Company will make payments of $50 million for each drillship on December 31, 2015, and DSME will extend all remaining milestone payments, $93.9 million for the Admiral and $305 million for the Archer, until their respective delivery dates. The Company retains the option to take earlier delivery of each vessel, subject to a forty-five (45) day notice period to DSME.

17 Dec 2015

Rig secured for drilling the Brasse prospect in Norway

Faroe, has entered into a contract with Transocean Offshore (North Sea) Ltd on behalf of the PL 740 joint venture for the lease of the semi-submersible Transocean Arctic drilling rig. Faroe has budgeted its net share of the well costs after tax to be less than £2m, and the well is expected to be drilled in the summer of 2016. .... [+ read more] Brasse will test a structure immediately to the south of the producing Brage field and if successful could be tied-back to Brage (Faroe 14.3%) or alternatively to other nearby installations. The co-venturer in the PL740 licence is Core Energy AS (50%).

17 Dec 2015

Rig contract cancellation

Statoil has decided to cancel the contract with Transocean for the drillship Discoverer Americas. The drillship has been on contract with Statoil since 2009, supporting Statoil’s exploration activities in East and North Africa and the Gulf of Mexico. Statoil was in the current environment unable to secure additional activity for the rig for the remainder of the contract period, ending in .... [+ read more] May 2016. “Discoverer Americas has been a very good performer for Statoil, contributing to test deep-water and ultra-deep water prospectivity in Tanzania, Egypt, and the Gulf of Mexico and appraising the multiple high-impact discoveries in Tanzania. All operations were performed with solid drilling efficiency and a good safety culture. Without additional activity lined up, we unfortunately have to let the rig go prior to contract end,” says Tore Aarreberg, head of rig procurement.

16 Dec 2015

Delivery of Songa Encourage

Songa Offshore has today taken delivery of Songa Encourage - the third Category D rig - from Daewoo Shipbuilding & Marine Engineering (DSME) in Korea. "We are pleased to take delivery of Songa Encourage today the 16 December 2015. This is the third Category D rig we take delivery of in a series of four rigs, all going on eight .... [+ read more] year contracts with Statoil in Norway. We are now looking forward to see the rig commence drilling operations in Norway", says CEO Bjørnar Iversen.

15 Dec 2015

Contract Cancellation

In accordance with the terms of the contract, Shell has terminated the rig's contract for convenience and will pay Noble for the remaining term at approximately 90 percent of the operating dayrate adjusted for certain other items. The rig is being mobilized to Singapore where it is expected to be stacked. .... [+ read more]

14 Dec 2015

Rig Contract Signed – Funding Secured for Skipper Drilling in the New Year

Independent Oil and Gas plc ("IOG" or the “Company”), the North Sea focused oil and gas company, is pleased to announce it has signed a Rig Contract with Transocean Drilling U.K. Limited (“Transocean”) to procure the Transocean John Shaw semi-submersible rig to drill the Company’s fully funded appraisal well on the Skipper oil discovery in Block 9/21a in the Northern North .... [+ read more] Sea in licence P1609. IOG anticipates that the rig will commence drilling operations at Skipper in late January or early February 2016 with the objective of retrieving good quality reservoir condition oil samples in order to design the optimum field development plan for the Skipper field. The rig will drill a vertical well to 5,600ft which is expected to take approximately 25 days. Skipper is an offshore heavy oil field located in the Northern North Sea with independently verified gross 2C resources of 26.2 MMBbls. IOG management estimates that Skipper has 34.1 MMBbls of recoverable oil based on a recovery factor of 25%, compared to the historic CPR estimate of 19%. The well will also target two exploration prospects directly beneath the Skipper oil discovery in the Lower Dornoch and Maureen formations, in which the CPR authors have mapped structures which could contain an additional 46 MMBbls of oil in place. (Source: AGR Tracs CPR dated September 2013.) If oil is present in these structures, it would be co-developed with Skipper in line with the Company’s hub strategy. IOG intends to drill the Skipper well as 100% owner, which requires completion of the Sale and Purchase agreement to acquire 50% of the licence from Alpha Petroleum Ltd (“Alpha”). As previously announced, the deadline for the completion of this agreement has been extended to 21 December 2015. The Company also requires the Oil and Gas Authority ("OGA") to approve IOG North Sea Limited as licence operator and AGR Well Management Limited ("AGR") as well operator.

14 Dec 2015

Rig Contract Signed – Funding Secured for Skipper Drilling in the New Year

Independent Oil and Gas plc ("IOG" or the “Company”), the North Sea focused oil and gas company, is pleased to announce it has signed a Rig Contract with Transocean Drilling U.K. Limited (“Transocean”) to procure the Transocean John Shaw semi-submersible rig to drill the Company’s fully funded appraisal well on the Skipper oil discovery in Block 9/21a in the Northern North .... [+ read more] Sea in licence P1609. IOG anticipates that the rig will commence drilling operations at Skipper in late January or early February 2016 with the objective of retrieving good quality reservoir condition oil samples in order to design the optimum field development plan for the Skipper field. The rig will drill a vertical well to 5,600ft which is expected to take approximately 25 days. Skipper is an offshore heavy oil field located in the Northern North Sea with independently verified gross 2C resources of 26.2 MMBbls. IOG management estimates that Skipper has 34.1 MMBbls of recoverable oil based on a recovery factor of 25%, compared to the historic CPR estimate of 19%. The well will also target two exploration prospects directly beneath the Skipper oil discovery in the Lower Dornoch and Maureen formations, in which the CPR authors have mapped structures which could contain an additional 46 MMBbls of oil in place. (Source: AGR Tracs CPR dated September 2013.) If oil is present in these structures, it would be co-developed with Skipper in line with the Company’s hub strategy. IOG intends to drill the Skipper well as 100% owner, which requires completion of the Sale and Purchase agreement to acquire 50% of the licence from Alpha Petroleum Ltd (“Alpha”). As previously announced, the deadline for the completion of this agreement has been extended to 21 December 2015. The Company also requires the Oil and Gas Authority ("OGA") to approve IOG North Sea Limited as licence operator and AGR Well Management Limited ("AGR") as well operator.

14 Dec 2015

Indonesia Sakti exploration well reaches total depth

KrisEnergy Ltd. (“KrisEnergy” or “the “Company”), an independent upstream oil and gas company, announces that it has completed drilling of the Mustika-1 exploration well in the Sakti production sharing contract (“PSC”) in the East Java Sea. Mustika-1 was drilled to a total measured depth of 2,768 feet (844 metres), or 2,667 feet total vertical depth subsea, and encountered gas in the .... [+ read more] Tuban and Kujung I formations. Initial indications from wireline logs are that the gases have a high carbon dioxide content and therefore are likely to be below the economic threshold for a commercial discovery. The well will be plugged and abandoned and a detailed analysis of the well data and gas samples will be undertaken to review the remaining prospects and leads in the Sakti PSC. Chris Gibson-Robinson, Director Exploration & Production, commented: “This is our final exploration well for 2015 with the first five being drilled in the Gulf of Thailand, all of which were successful. The first four wells resulted in the recently approved plan of development for the Rossukon field." KrisEnergy was awarded the Sakti PSC in February 2014. The block covers 4,974 sq. km in the East Java Sea over the western margin of the East Java Basin, Bawean Arch and the Muriah Trough. KrisEnergy is also the operator of the Bulu PSC, which is adjacent to the Sakti PSC and contains the Lengo gas discovery for which the Company received approval for its plan of development in December 2014. Front-end engineering design for the Lengo development was completed in the third quarter of 2015. Gas sales negotiations are ongoing and preparations are underway to tender the contract for engineering, procurement, construction and installation.

14 Dec 2015

VAALCO Energy Announces Second Successful Well Drilled To The Dentale Formation

VAALCO Energy, Inc. (NYSE: EGY) today announced that the North Tchibala 2-H well, the second development well drilled by VAALCO in the North Tchibala field, was brought online at a stabilized rate of approximately 500 gross barrels of oil per day (BOPD), or 122 BOPD net revenue interest to VAALCO. The well was drilled to a measured depth of 16,476 .... [+ read more] feet and encountered good quality sands in the Dentale D-18/19 reservoir. The well came on production flowing naturally with no H2S and water free. Based on production tests in nearby exploration wells, the quality of the reservoir would indicate the potential for a higher flow rate than has been achieved thus far. VAALCO is gathering diagnostic data to assess the productive capacity of the North Tchibala 2-H well and to determine if there is remedial work that might increase the flow rate from the well. While the Dentale formation is productive in onshore Gabon fields, the North Tchibala field represents the first Dentale production developed in the offshore waters of Gabon. The first North Tchibala producer, North Tchibala 1-H, targeted the shallower Dentale D-9 formation at approximately 11,200 feet measured depth and was placed on production during the third quarter of 2015. The North Tchibala 1-H well initially produced at a sustained rate of 3,000 BOPD flowing naturally for six weeks with minimal pressure depletion. In late October, the Company observed a decline in bottomhole pressure accompanied by an increase in gas production rates. The well was choked back to approximately 1,500 BOPD and bottomhole pressure has now stabilized. Production continues to remain at that level, which is still at initial expectations for the well. VAALCO will continue to monitor both Dentale wells and take appropriate actions to optimize long term production and reservoir performance. The North Tchibala 2-H is the third successful well drilled and placed on production at VAALCO's new Southeast Etame/North Tchibala (SEENT) platform located in approximately 260 feet of water offshore Gabon. VAALCO is the operator of the Etame Marin permit area and owns a 28.1% working interest and a 24.4% net revenue interest. The Transocean Constellation II jackup rig has mobilized to the nearby Avouma/South Tchibala platform to conduct workover operations to replace electrical submersible pumps (ESPs) on three existing production wells, two of which are off production. Sea conditions have improved allowing the safe movement of the rig. Steve Guidry, VAALCO's Chairman and CEO commented, "I am pleased to announce that the North Tchibala 2-H well encountered very good quality reservoir. As a result, we are further encouraged about the long term upside potential for the Dentale formation on our Etame Marin acreage, but it will take time to monitor the ongoing performance of the first two wells and to test other areas of our concession with additional wells in the future. While no more wells are planned for the SEENT platform in the near term, we are evaluating the drilling of a development well at the Etame platform in early 2016 following our three-well workover program. The Etame development well would target the Gamba formation as well as test the Dentale reservoir that we believe could exist at deeper depths in that area."

14 Dec 2015

Expansion of Maersk Guardian

Semco Maritime has entered into an agreement with Maersk Drilling for the expansion of accommodation rig Maersk Guardian, which will be inserted at various fields in the Danish part of the North Sea from September 2016 The DKK three-digit million order for Semco Maritime comprises installation of new accommodation blocks as a supplement to existing quarters on the jack-up rig. .... [+ read more] Semco Maritime won the order in an open tender with several Danish and foreign participants. Head of Semco Maritime’s rig division, Senior Vice President Lars Skov Christensen, is very pleased with the order for Maersk Guardian, which is strategically important in a market under pressure. - It is very encouraging that an internationally respected operator such as Maersk Drilling chooses us. That confirms that our strategy is competitive in a challenged rig market. Lars Skov Christensen to a large extent ascribes the win to Semco Maritime’s shipyard-in-a-box concept. - Our shipyard-in-a-box concept is a figurative concept of flexibility, which allows us to swiftly relocate our rig engineers to where the work is. We can move out in a matter of a few hours or days, depending on the type of the assignment or the geographical location of where we are going. The concept simultaneously minimizes our fixed costs without compromising quality, Lars Skov Christensen states. Maersk Guardian is currently located in Frederikshavn, where the rig will be situated during the entire refurbishing period. The largest part of the Semco order – construction of the new accommodation blocks – is performed in Gdansk in Poland. The entire accommodation block unit is then sailed to Frederikshavn and installed on the rig, Vice President and main responsible for the project Nikolaj Vejlgaard explains: - We have never constructed an accommodation block this size before. The sheer size makes it impossible for us to perform the work at our own facilities in Esbjerg, and we have therefore placed the assignment with our skilled collaboration partners in Poland, said Nikolaj Vejlgaard. The 142-room accommodation block weighs 560 ton and is set to arrive at Frederikshavn in August with subsequent final installation of the entire block a couple of weeks later. Maersk Guardian has a leg length of 157 meters and was constructed in Japan in 1986. It is designed for all-year operation in the North Sea.

14 Dec 2015

Launching Ceremony for the Tam Dao 05 Jackup

On 13 Dec 2015, Petrovietnam Marine Shipyard held the launching ceremony for the Tam Dao 05 jackup. The rig is expected to be delivered after 32 month of construction. .... [+ read more]

14 Dec 2015

Atlantica Delta Semi Tender Delivered

December 11, 2015 Atlantica Delta semi tender was delivered by DSIC (Dalian). The Delta will be loaded aboard the Mighty Servant III for the 10,000 nautical mile, 5 week voyage to West Africa where it will immediately commence a term development drilling contract for Total Congo. The Delta will be positioned in 800m of water with pre-laid mooring adjacent .... [+ read more] to the recently delivered Moho Nord TLP.

10 Dec 2015

Minor oil discovery near the Vega Sør field in the north-eastern North Sea - 35/11-18 and 18 A

Wintershall Norge AS, operator of production licence 248, is in the process of completing the drilling of wildcat well 35/11-18 and appraisal well 35/11-18 A. The wells have been drilled approx. four kilometres west of the Vega Sør field. The primary exploration target for well 35/11-18 was to prove petroleum in Middle Jurassic reservoir rocks (the Brent group). The secondary .... [+ read more] exploration target was to prove petroleum in Upper Jurassic reservoir rocks (sandstones in the Heather formation). In the primary exploration target, the well encountered a 275 metre thickness of moderate to good reservoir quality in the Brent group. The well proved light oil in the Tarbert and Oseberg formation, with columns of eleven and three metres, respectively. In the secondary exploration target, the well encountered an eight-metre hydrocarbon column of good to poor reservoir quality. The objective of appraisal well 35/11-18 A was to investigate the extent of the reservoir and the hydrocarbon columns. The well was drilled about 450 metres south of the discovery well. The well proved gas and oil in two Upper Jurassic (the Heather formation) sandstones with net thicknesses of 33 and 24 metres, respectively, with poor to good reservoir quality. The well encountered oil throughout the Brent group, which is 270 metres, with moderate to good reservoir quality. The well also encountered a 46-metre column of light oil in the Lower Jurassic (the Cook formation). Preliminary estimates place the size of the discovery between 1 and 3 million Sm3 of recoverable oil. Extensive data collection and sampling have been carried out, including two formation tests in the Cook and Oseberg formation in 35/11-18 A. The tests show good flow properties with stable flow pressure and low pressure drop, with good permeability. The wells are the second and third exploration wells in production licence 248. Well 35/11-18 was drilled to a measured depth of 3759 metres below the sea surface (3709 metres vertical depth) and was terminated in Early Jurassic rocks (the Cook formation). The appraisal well was drilled to a measured depth of 4020 metres below the sea surface (3874 metres vertical depth), and was terminated in Early Jurassic rocks (the Statfjord group). Water depth at the site is 366 metres. The wells have been permanently plugged and abandoned. The partners in PL 248 will now evaluate the results. Wells 35/11-18 & 18 A were drilled by the Borgland Dolphin drilling facility, which will now drill appraisal well 25/10-14 in the North Sea in production licence 571, where Suncor Energy Norge AS is the operator.

7 Dec 2015

Transocean Ltd. Announces Two Year Contract For The Henry Goodrich

Transocean Ltd. announced today that the harsh-environment semisubmersible Henry Goodrich was awarded a two year contract with Husky Oil Operations Limited offshore Canada at a dayrate of $275,000. The estimated contract backlog excluding mobilization is $200 million. The rig is expected to commence operations in the second quarter of 2016. As of December 6, 2015, the company's contract backlog is approximately .... [+ read more] $16.8 billion.

7 Dec 2015

Maersk Drilling secures 5-year accommodation contract for jack-up Maersk Guardian

Maersk Drilling has been awarded a contract with Maersk Oil for the jack-up rig Maersk Guardian for accommodation on various fields in the Danish part of the North Sea. The firm contract duration is 5 years with commencement in September 2016. The contract includes two 1-year options. The estimated contract value for the firm contract period is USD 142m. “We .... [+ read more] are pleased that we will get Maersk Guardian back on the water. In this market, it is important to seek out new ideas in order to keep our rigs employed. An accommodation contract like this is a good example of that and it adds to our contract backlog,” says Morten Pilnov, Head of Global Sales in Maersk Drilling. The Maersk Guardian is currently stacked in Frederikshavn where it will be located throughout the refurbishment period until contract commencement. The work entails decommissioning of the cantilever including drilling package, overhaul of auxiliary systems to support accommodation units, overhaul of existing accommodation block on the rig and installation of new accommodation modules. Built in 1986 in Japan, the Maersk Guardian is designed for year-round operation in the North Sea with a leg length of 132 meters.

7 Dec 2015

KrisEnergy kicks off Sakti exploration well in East Java Sea

– KrisEnergy Ltd. (“KrisEnergy” or “the “Company”), an independent upstream oil and gas company, announces that the KS Java Star jack-up rig has commenced drilling of the Mustika-1 exploration well in the KrisEnergy-operated Sakti production sharing contract (“PSC”). Drilling is expected to take approximately 20 days. Mustika-1, which is targeting the Kujung I formation, is planned to reach a total measured .... [+ read more] depth at 3,100 feet (945 metres), or 3,000 feet total vertical depth subsea. The location of the well is based on the interpretation of the 1,202 km 2D and 401 sq. km 3D seismic data acquired by the Company in 2014. KrisEnergy is also the operator of the Bulu PSC, which is adjacent to the Sakti PSC and contains the Lengo gas discovery for which the Company received approval for its plan of development in December 2014. Chris Gibson-Robinson, Director Exploration & Production, said: “The decision to drill Mustika-1 at this time comes as we are finalising project details for the Lengo development. This prospect is 10 km west of Lengo and, if successful, we would look at producing Sakti gas through the Lengo facilities.” Front-end engineering design for the Lengo development was completed in the third quarter of 2015. Gas sales negotiations are ongoing and preparations are underway to tender the contract for engineering, procurement, construction and installation. KrisEnergy was awarded as the operator a 95% working interest in the Sakti PSC in February 2014. The block covers 4,974 sq. km in the East Java Sea over the western margin of the East Java Basin, Bawean Arch and the Muriah Trough. Golden Heaven Jaya Ltd. holds the remaining 5% working interest.

7 Dec 2015

Lundin Petroleum commences Imbok exploration well, offshore Malaysia

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that its wholly owned subsidiary Lundin Malaysia BV (Lundin Malaysia) has commenced drilling of the Imbok-1 exploration well in Blocks SB307 and SB308, offshore East Malaysia. The Imbok prospect is in shallow water and lies to the east and south of two major producing fields in offshore East Malaysia. The well will .... [+ read more] target hydrocarbons in Miocene aged sands. Imbok-1 will be drilled with the West Prospero jack-up rig to a total depth of approximately 1,700 metres below mean sea level. The drilling of the well is expected to take approximately 30 days. Lundin Malaysia holds 85 percent working interest in SB307 and SB308. Partner is PETRONAS Carigali Sdn Bhd with 15 percent working interest. Lundin Malaysia operates seven blocks in Malaysia, namely PM307, PM319, PM308A, PM308B, PM328, SB307/308 and SB303.

7 Dec 2015

Songa Equinox commencement of drilling contract

Songa Equinox has today commenced drilling operations under its eight-year drilling contract with Statoil at the Troll Field on the Norwegian continental shelf, and the rig is now on operating rate. Songa Equinox is the first rig in a series of four Category D semi-submersible drilling rigs, specifically built for and contracted to Statoil. "The start of drilling operations for .... [+ read more] Songa Equinox is another milestone in the Cat D project. Our organization is looking forward to working collaboratively with Statoil over the next eight years", says Songa Offshore's CEO, Bjørnar Iversen.

7 Dec 2015

Consent for drilling operations using COSLInnovator

Statoil Petroleum AS has received consent to use the COSLInnovator mobile drilling facility for drilling, completion, intervention, workover and well plugging on the Troll field. COSLInnovator is a semi-submersible drilling facility constructed at the Yantai Raffles Shipyard in China. The facility was issued with an Acknowledgement of Compliance (AoC) by the PSA in 2012, and has been on contract to Statoil .... [+ read more] on the Troll field since then. The Petroleum Safety Authority Norway has now granted Statoil consent for well operations in accordance with Statoil's application.

7 Dec 2015

Consent to use Songa Equinox on the Troll field

The PSA has given Statoil consent to use the Songa Equinox mobile drilling facility for drilling and completion of wells on the Troll field in production licences 054 and 085. Songa Equinox is a semi-submersible drilling facility and the first of four Cat D rigs that Songa is building for Statoil. Songa Equinox received an Acknowledgement of Compliance (AoC) from .... [+ read more] the PSA in November 2015. The Troll field is located around 65 kilometres west of Kollsnes in Hordaland County and is the largest gas discovery made in the North Sea. The Petroleum Safety Authority Norway has now granted consent to use Songa Equinox on the Troll field in accordance with Statoil's application.

7 Dec 2015

Consent for drilling operations using COSLPromoter

Statoil Petroleum AS has received consent to use the COSLPromotor mobile drilling facility for drilling, completion, intervention, workover and well plugging on the Troll field. COSLPromoter is a semi-submersible dynamically positioned drilling facility, type GM4000. The facility was built and assembled at Yantai Raffles Shipyard (YRS) in China. The drilling package was delivered by National Oilwell Varco (NOV) and built at .... [+ read more] Nymo in Grimstad. The facility was issued with an Acknowledgement of Compliance (AoC) by the PSA in 2012. The Petroleum Safety Authority Norway has now granted Statoil consent for well operations in accordance with Statoil's application.

2 Dec 2015

Songa Offshore has received the PSA's Acknowledgement of Compliance (AoC) for Songa Equinox

t is the PSA's assessment that petroleum activities may be carried out using the Songa Equinox facility within the regulatory framework. The validity of the Acknowledgement of Compliance assumes that Songa Offshore ensures that the facility and relevant parts of the company’s organisation and management systems are maintained, to fulfil the terms and conditions set out in the PSA’s decision. .... [+ read more]

1 Dec 2015

Maersk Drilling secures contract for Maersk Venturer with Total

Maersk Drilling has been awarded a contract for the drillship Maersk Venturer with oil major Total. The contract covers one exploration well (estimated duration 120 days) in block 14 offshore Uruguay. The estimated contract value for the programme is USD 44m excluding mobilisation. The drilling programme is expected to commence in March 2016. “We have collaborated and partnered with .... [+ read more] Total many times over the years. Total is a highly valued customer of Maersk Drilling, and we are very pleased with being selected by Total to drill their first exploration well offshore Uruguay,” says Claus V. Hemmingsen, CEO in Maersk Drilling and member of the Executive Board in the Maersk Group and continues: “With this contract, we continue to build our contract backlog and secure work for our rigs and people, which is very encouraging in this challenging market.” Maersk Venturer is the third in a series of four ultra deepwater drillships in Maersk Drilling’s fleet. The four drillships represent a total investment of USD 2.6bn. The other three drillships have all secured long-term contracts.

1 Dec 2015

Primeline Completes LS30-3-1 Well

Primeline Energy Holdings Inc. (“Primeline” or the “Company”) (TSXV: PEH) today announced that drilling operations of the LS30-3-1 well have been completed without discovering hydrocarbons LS30-3-1 is located approximately 20km north of the LS36-1 gas field platform and was targeting a large channel sand prospect as part of Primeline’s two well exploration drilling programme for 2015. The well spudded on .... [+ read more] November 13. When the well reached the planned total depth of 1800m, Primeline decided to deepen the well, drilling to a total depth of 2000m on November 27 with electronic log data being collected during November 27-30. The analysis of the results shows that whilst the well encountered three sets of very good sandstone reservoir sequences as predicted, unfortunately there was no oil or gas accumulation in those sandstones. The LS30-3-1 has thus been declared as a dry well and the plug and abandon operation is now ongoing before the rig is released. Primeline will conduct a careful post well evaluation of the results of the LS23-1-1 and LS30-3-1 wells in the coming months in order to formulate the next stage of the exploration programme in the remainder of the 5,877sq km of Block 33/07.

30 Nov 2015

Drilling permit for well 16/4-10 in production licence 544

The Norwegian Petroleum Directorate (NPD) has granted Lundin Norway AS a drilling permit for well 16/4-10, cf. Section 8 of the Resource Management Regulations. Well 16/4-10 will be drilled from the Island Innovator drilling facility in position 58°35’03.08’’ north 02°10’21.95’’ east. The drilling programme for well 16/4-10 relates to drilling of a wildcat well in production licence 544. Lundin is .... [+ read more] the operator with an ownership interest of 40 per cent. The other licensees are Bayerngas Norge AS and Lime Petroleum Norway AS, each with 30 per cent. The area in this licence consists of part of block 16/4. The well will be drilled southwest of the 16/4-6 S oil discovery (Luno II) in the central part of the North Sea. Production licence 544 was awarded on 19 February 2010 (APA 2009). This is the second exploration well to be drilled within the licence area. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

30 Nov 2015

Rig contract to Transocean

Det norske oljeselskap ASA has on behalf of the partnerships in PL 203 (Alvheim) and PL 150 (Volund) awarded an agreement to Transocean Offshore (North Sea) Ltd NUF for the lease of the semi-submersible drilling rig Transocean Arctic. The contract scope for drilling of four wells in the Alvheim area (estimated to 250 days (has a market value of approximately USD .... [+ read more] 44.75 million exclusive options. The contract has its commencement window during December 2016 and involves the drilling of one exploration well (West Volund in license 150B) and three production wells (two wells in license 150 and one in license 203 / 088BS respectively). The award is for a traditional well contract based on a daily rate and with several flexible options built into the agreement. The Transocean Arctic is a harsh environment midwater semi-submersible drilling rig also certified for drilling wells in the Barents Sea and under HPHT (high pressure and high temperature) conditions.

26 Nov 2015

Grand ceremony for the first of three rigs built by North Sea Rigs

Several hundred people were present at the naming ceremony of North Sea Rig’s first rig, North Dragon, at the CIMC Raffles yard in Yantai, China, today. The rig company and its owners take a long-term perspective, providing rigs for cost efficient, safe and effective operations. North Dragon, Beacon Atlantic and Beacon Pacific all have a design (GM4-D) .... [+ read more] based on CIMC Raffles’ previous construction projects with rigs adapted for operations in a harsh environment. The concept has also adopted the best elements of new rig projects such as Statoil’s CAT D.

26 Nov 2015

Lundin Petroleum completes Selada exploration well, offshore Malaysia

Lundin Petroleum AB (Lundin Petroleum) announces that its wholly owned subsidiary Lundin Malaysia BV (Lundin Malaysia) has completed the Selada-1 exploration well in Block PM308A, offshore Malaysia. The well was dry and has been plugged and abandoned. The well was targeting hydrocarbons in Miocene aged sands approximately 14 km to the south of the Bertam field operated by Lundin Malaysia. Selada-1 .... [+ read more] was drilled with the West Prospero jack-up rig. Lundin Malaysia holds 75 percent working interest in PM308A. Partner is PETRONAS Carigali Sdn Bhd with 25 percent working interest. Lundin Malaysia operates seven blocks in Malaysia, namely PM307, PM319, PM308A, PM308B, PM328, SB303 and SB307/308.

25 Nov 2015

Roc-1 well update

Carnarvon Petroleum Limited is pleased to advise that the operator of the Roc-1 well, Quadrant Energy has advised that the well spud on 24 November 2015. Drilling is expected to take approximately 35 to 40 days trouble free to reach Total Depth of 4,700m. .... [+ read more]

24 Nov 2015

Lundin Petroleum spuds exploration well on the Ørnen prospect in the Barents Sea South

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that its wholly owned subsidiary Lundin Norway AS (Lundin Norway) has commenced drilling of exploration well 7130/4-1 on the Ørnen prospect. The well 7130/4-1 will explore the Ørnen prospect in PL708, located on the eastern parts of the Finnmark Platform in the southern Barents Sea. The reservoir is expected to consist of .... [+ read more] Upper Permian carbonates. The Ørnen prospect is estimated to contain gross unrisked prospective resources of 354 million barrels of oil equivalents (MMboe). The planned total depth is approximately 2,630 metres below mean sea level and the well will be drilled with the semi-submersible drilling unit Transocean Artic. The drilling operation is expected to take approximately 60 days. Lundin Norway is the operator of PL708 with a 40 percent working interest. The partners are Edison Norge with 20 percent, Lukoil Overseas North Shelf with 20 percent, Lime Petroleum Norway with 10 percent and North Energy with 10 percent.

23 Nov 2015

Isobel Deep Re-drill Well Spud

Falkland Oil and Gas Limited (AIM:FOGL), the oil and gas exploration company focused on its extensive license areas to the North, South and East of the Falklands islands, is pleased to announce that the 14/20-2 ‘Isobel 2’ well (the "Well") was spudded, by Premier Oil as operator, on 21 November 2015. The well is located on licence PL004a , .... [+ read more] in which FOGL has a 40% working interest, and lies approximately 4 km away from the 14/20-1 Isobel Deep oil discovery. The well will target the Isobel Deep reservoir and is a re-drill of the 14/20-1 well drilled earlier this year, which failed to reach Total Depth owing to operational issues. The well will test the F3 fan systems, which are mapped as entering the basin from the south east margin and comprise a sequence of stacked reservoirs. In addition to Isobel Deep, the well will also penetrate four other fans within the complex, comprising: Elaine South, Isobel, Doreen and Irene. The Elaine/Isobel fan complex, based on the operator’s estimates, has multiple reservoir targets and gross, mean un-risked resources of 400 million barrels of oil. A further release will be issued once the well has been completed and this is expected to be in January 2016. FOGL is fully carried through the costs of this well by Premier Oil and Rockhopper Exploration.

20 Nov 2015

Minor gas/oil/condensate discovery near the Visund field in the North Sea – 34/8-16 S

Statoil Petroleum AS, operator of production licence 120, has completed drilling of exploration well 34/8-16 S. The well was drilled on the east flank of the Visund field in the northern part of the North Sea, and about 140 km northwest of Bergen. The primary exploration target for 34/8-16 S was to prove gas and/or gas condensate in the Middle .... [+ read more] Triassic (the Lomvi formation). The secondary exploration target was to investigate additional resources in Lower to Middle Jurassic reservoir rocks (the Statfjord and Brent Group) and Upper Triassic reservoir rocks (the Lunde formation). The well encountered an oil/gas/condensate column of about 85 metres in the Lunde formation, 40 metres of which were of moderate to good reservoir quality. The Brent group is not present. Preliminary calculations of the size of the discovery are between 0.4 and 1.1 million Sm³ of recoverable oil equivalents. The licensees will consider further development of the discovery in the context of other potential additional resources. The well was not formation tested, but comprehensive data collection and sampling were carried out. This is the 26th exploration well drilled in production licence 120. Well 34/8-16 S was drilled to a vertical and measured depth of 3875 and 3830 metres below sea level, respectively, and was terminated in the Hegre group in the Triassic. The water depth at the site is 380 metres. The well will now be permanently plugged and abandoned. The well was drilled by the Songa Trym drilling facility.

17 Nov 2015

Termination Of Rig Construction Contract With PPL Shipyard Pte Ltd For The Construction Of A High-Specification Jack-Up Rig

MP Drilling has today issued PPL, the builder of the New Rig, a notice of termination of the Rig Construction Contract following the latter's failure to comply with certain of its material contractual obligations. In arriving at this decision to terminate the Rig Construction Contract, MP Drilling has taken into account various factors including cracks found on all three legs of .... [+ read more] the New Rig during two rounds of tests, notwithstanding repair works carried out by PPL after the first round of tests. In view of the termination of the Rig Construction Contract, MP Drilling will not be taking delivery of the New Rig and it will be seeking, among others, a refund from PPL of the initial amount of 10% of the contract price (approximately US$21.4 million) previously made to PPL pursuant to the Rig Construction Contract together with interest.

16 Nov 2015

Completion of Well Operations on the Aje Field, Nigeria

Panoro Energy ASA, the independent E&P company with assets in Nigeria and Gabon, is pleased to announce the completion of well operations on the Aje field on the OML 113 license offshore Nigeria. The Aje-4 well, which was previously drilled in 2008, has been successfully completed as an oil production well. This follows the previously reported successful completion of the .... [+ read more] Aje-5 production well. Both wells have been perforated in the Cenomanian oil bearing zones with positive indications of well productivity based on the short flow-backs carried out during the completion programs. Subsea trees have been installed on both wells, and the wells are now suspended ready for connection to the oil production facilities, prior to commencement of production. The Saipem Scarabeo 3 is currently being demobilized. No safety related incidents have been reported. Based on the well results and updated perforation modelling, management is confident that it should meet its indicated daily production guidance.

16 Nov 2015

Primeline Commenced Drilling Of LS30-3-1 Well

Primeline Energy Holdings Inc. today announces that it has commenced the drilling operations of the LS30-3-1 well. Following the plug and abandon operation of LS23-1-1 announced on October 28, Primeline’s contractor, China Oilfield Service Ltd. (“COSL”), towed the rig HYSY 941 to theLS30-3-1 location on November 4 and successfully jacked up the rig on location on November 7. COSL subsequently .... [+ read more] completed all the necessary preparation work and Primeline obtained the operation licence. LS30-3-1 well was then spudded on November 13 and drilling is ongoing. LS30-3-1 is located approximately 20km north of the LS36-1 gasfield platform and is targeting a large channel sand prospect. The planned total depth of the well is 1,800m, targeting the same reservoir as that of the LS36-1 gasfield. The drilling time is anticipated to be around 25 days. The drilling of LS30-3-1 is part of the 2 well exploration drilling programme by Primeline in 2015 as part of the rolling development programme anchored on the LS36-1 production.

13 Nov 2015

Drilling permit for well 7130/4-1 in production licence 708

The Norwegian Petroleum Directorate has granted Lundin Norway AS a drilling permit for well 7130/4-1, cf. Section 8 of the Resource Management Regulations. Well 7130/4-1 will be drilled from the Transocean Arctic drilling facility in position 71°31’55.66? north and 30°10’07.90? east, after completing the drilling of wildcat well 6406/12-5 S in production licence 586 for VNG Norge AS. The drilling .... [+ read more] programme for well 7130/4-1 relates to the drilling of an exploration well in production licence 708 where Lundin Norway AS is the operator with an ownership interest of 40 per cent. The other licensees are Lukoil Overseas North Shelf AS (20 per cent), Edison Norge AS (20 per cent), Lime Petroleum Norway AS (10 per cent) and Pure E&P Norway AS (10 per cent). The area in this licence consists of block 7130/7 and the southern half of block 7130/4. The well will be drilled about 85 kilometres north of Berlevåg in Finnmark. Production licence 708 was awarded on 21 June 2013 (22nd licensing round). This is the first well to be drilled in the licence. The permit is contingent on the operator securing all other permits and consents required by other authorities prior to commencing the drilling activity.

13 Nov 2015

Lundin Petroleum spuds exploration well on the Lorry prospect, offshore Norway

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that its wholly owned subsidiary Lundin Norway AS (Lundin Norway) has commenced drilling of exploration well 6407/10-4 on the Lorry prospect. The well 6407/10-4 will explore the Lorry prospect in PL700, located on the northern part of the Frøya High in the Norwegian Sea approximately 17 km northeast of VNG Norge operated .... [+ read more] Pil and Bue discoveries in the Halten Terrace. The reservoir is expected to consist of Upper Jurassic sandstone. The Lorry prospect is estimated to contain gross unrisked prospective resources of 151 million barrels of oil equivalents (MMboe). The planned total depth is approximately 3,104 metres below mean sea level and the well will be drilled with the semi-submersible drilling unit Island Innovator. The drilling operation is expected to take approximately 60 days. Lundin Norway is the operator of PL700 with a 40 percent working interest. The partners are Bayerngas Norge AS, GDF SUEZ E&P Norge AS and VNG Norge AS with 20 percent each.

13 Nov 2015

Drilling permit for well 7130/4-1 in production licence 708

The Norwegian Petroleum Directorate has granted Lundin Norway AS a drilling permit for well 7130/4-1, cf. Section 8 of the Resource Management Regulations. Well 7130/4-1 will be drilled from the Transocean Arctic drilling facility in position 71°31’55.66? north and 30°10’07.90? east, after completing the drilling of wildcat well 6406/12-5 S in production licence 586 for VNG Norge AS. The drilling .... [+ read more] programme for well 7130/4-1 relates to the drilling of an exploration well in production licence 708 where Lundin Norway AS is the operator with an ownership interest of 40 per cent. The other licensees are Lukoil Overseas North Shelf AS (20 per cent), Edison Norge AS (20 per cent), Lime Petroleum Norway AS (10 per cent) and Pure E&P Norway AS (10 per cent). The area in this licence consists of block 7130/7 and the southern half of block 7130/4. The well will be drilled about 85 kilometres north of Berlevåg in Finnmark. Production licence 708 was awarded on 21 June 2013 (22nd licensing round). This is the first well to be drilled in the licence. The permit is contingent on the operator securing all other permits and consents required by other authorities prior to commencing the drilling activity.

13 Nov 2015

Roc-1 well update

Carnarvon Petroleum Limited (“Carnarvon”) (ASX:CVN) is pleased to advise that the operator of the Roc-1 well, Quadrant Energy has now received the Noble Tom Prosser drilling rig. The rig will mobilise to the Roc-1 well site in WA-437-P and prepare for spud around 17 November 2015. The Roc-1 well will target the same Lower Keraudren reservoir in which oil was discovered .... [+ read more] in the 2014 Phoenix South-1 well by the same joint venture partners in the adjoining WA-435-P. Contingent on the success case, the plan is to re-enter the Roc-1 well bore in Q3, 2016 for comprehensive testing (including flow testing) and coring.

12 Nov 2015

Harland and Wolff completes Byford Dolphin Contract

Harland and Wolff completed the dry docking and SPS Class Renewal Survey of the Byford Dolphin Mobile Offshore Drilling Unit (MODU) during the summer. The rig left Belfast following a six-month dry docking in the ship yard's main Building Dock. Harland and Wolff Director of Marine and Offshore Unit Repair, James Lappin, said "Over the years Harland and Wolff and .... [+ read more] Dolphin Drilling have collaborated on several occasions, having fabricated pontoons, column extensions, power generation and accommodation modules for other vessels in the Dolphin fleet."

12 Nov 2015

Kosmos Energy Makes Second Major Gas Discovery Offshore Mauritania

Kosmos Energy (NYSE: KOS) announced today that the Marsouin-1 exploration well, located in the northern part of Block C-8 offshore Mauritania, has made a significant, play-extending gas discovery. This is the company’s second major discovery of 2015. Based on preliminary analysis of drilling and wireline logging results, Marsouin-1 encountered at least 70 meters (230 feet) of net gas pay in .... [+ read more] Upper and Lower Cenomanian intervals comprised of excellent quality reservoir sands. Located approximately 60 kilometers north of the basin-opening Tortue-1 gas discovery (renamed Ahmeyim), Marsouin-1 was drilled in nearly 2,400 meters of water. “Marsouin-1 is our second major discovery of 2015, extending our 100 percent success rate in the outboard Cretaceous petroleum system offshore Mauritania and Senegal. Well-to-seismic calibration has significantly de-risked the discovered resource base, as well as future prospects in the basin. Importantly, the well results have validated our charge model and given us growing confidence in our ability to predict the oil and gas potential of this emerging, large-scale petroleum system. We have a disciplined exploration and appraisal program planned to further unlock the basin,” said Andrew G. Inglis, chairman and chief executive officer. The Atwood Achiever drillship will now proceed to the Ahmeyim-2 location in the southern part of Mauritania’s Block C-8 where it will drill the top-hole section of the well. The drillship is then expected to sail to Senegal where it will spud Guembeul-1, the first in a series of wells to delineate the Greater Tortue area, before year-end.

10 Nov 2015

Dry well near the Njord field in the Norwegian Sea – 6406/12-5 S

VNG Norge AS, operator of production licence 586, is in the process of completing the drilling of wildcat well 6406/12-5 S. The well has been drilled about 33 kilometres southwest of the Njord field and about five kilometres southeast of the 6406/12-3 S (Pil) discovery in the Norwegian Sea. The purpose of the well was to prove petroleum in reservoir .... [+ read more] rocks from the Upper Jurassic (the Rogn and Melke formations). The well encountered about 12 metres of sandstone in the Rogn formation with moderate reservoir quality. The well also encountered 31 metres of sandstone in intra Spekk formation and 182 meters of sandstone in the Melke formation, both with moderate reservoir quality. The reservoir only has traces of oil. The well is classified as dry. Data acquisition and sampling have been carried out. This is the sixth exploration well in production licence 586. The licence was awarded in APA 2010. Well 6406/12-5 S was drilled to a vertical depth of 3710 metres and a measured depth of 4297 metres below the sea surface and was terminated in the Melke formation in the Upper Jurassic. The water depth at the site is 336 metres. The well will now be permanently plugged and abandoned. Well 6406/12-5 S was drilled by the Transocean Arctic drilling facility, which now will drill wildcat well 7130/4-1 in production licence 708 in the Barents Sea, where Lundin Norway AS is the operator.

10 Nov 2015

Paragon Extends Delivery of High Specification Jackup Prospector 7

Paragon offshore has reported that one of its wholly-owned subsidiaries has signed an agreement with Shanghai Waigaoqiao Shipbuilding Co., LTD., to push back the delivery date of the high specification Friede and Goldman JU-2000E jackup Prospector 7 jackup rig by 12 months after the unit has been technically accepted. The unit will now be delivered from the yard towards the end .... [+ read more] of December 2016.

10 Nov 2015

Sea Lion-1 Final Drilling Progress Report

3D Oil Limited (ASX: TDO) advises that wireline evaluation and sampling of formation fluids over zones of interest identified on preliminary Sea Lion -1 data have been completed. This work has confirmed that no zones of commercial hydrocarbons were encountered in the Sea Lion-1 well. Current operation is running out of the hole with logging tools. Forward operations are to plug .... [+ read more] and abandon the Sea Lion -1 well and to de-mobilise the West Telesto drilling rig from the site. This is the final Drilling Progress Report for Sea Lion -1. TDO will advise when all site operations are compete and the West Telesto has been released. Sea Lion is located in offshore Gippsland Basin permit VIC/P57 where 3D Oil has a 24.9% interest in Vic/P57 while the company’s share of Sea Lion-1 well costs is being carried up to the extent of US$7.5 million as part of an agreement with joint venture operator Carnarvon Hibiscus Pty Ltd (‘CHPL’) the wholly owned subsidiary of Hibiscus Petroleum.

10 Nov 2015

Atwood Oceanics Announces Contract Extension for the Atwood Advantage

Atwood Oceanics, Inc. (NYSE: ATW) announced today that one of its subsidiaries agreed to an extension and rate adjustment to its existing contract with Noble Energy, Inc. for the ultra-deepwater rig, the Atwood Advantage, effective November 9, 2015. The agreement is to extend the contract for the purposes of a plugging and abandoning four well program in the Gulf .... [+ read more] of Mexico that has an estimated duration of one hundred and twenty (120) days during the contract term and is anticipated to occur in 2016. This extension adjusts the operating day rate to approximately $240,000 per day only during the four plug and abandon wells and makes the new contract expiry date approximately August 2017.

10 Nov 2015

Atwood Oceanics announces that it has been chosen for exclusive negotiations for one of its drillships under construction

Atwood Oceanics, Inc. (NYSE: ATW) announced today that one of its subsidiaries has received a letter confirming that it has been chosen to enter exclusive negotiations with an undisclosed operator to conclude agreement on a drilling program offshore Brazil commencing in the third quarter of 2017. The letter specifies that either the Atwood Admiral or Atwood Archer, ultra-deepwater drillships .... [+ read more] currently under construction at the Daewoo Shipbuilding & Marine Engineering Co., Ltd yard in South Korea, would be contracted to drill the program. The letter specifies a number of contractual items that have been agreed by the parties, including the commercial rates, well count, minimum term length, and rig acceptance criteria.

10 Nov 2015

Atwood Oceanics announces hat it has been chosen for exclusive negotiations for one of its drillships under construction

Atwood Oceanics, Inc. (NYSE: ATW) announced today that one of its subsidiaries has received a letter confirming that it has been chosen to enter exclusive negotiations with an undisclosed operator to conclude agreement on a drilling program offshore Brazil commencing in the third quarter of 2017. The letter specifies that either the Atwood Admiral or Atwood Archer, ultra-deepwater drillships .... [+ read more] currently under construction at the Daewoo Shipbuilding & Marine Engineering Co., Ltd yard in South Korea, would be contracted to drill the program. The letter specifies a number of contractual items that have been agreed by the parties, including the commercial rates, well count, minimum term length, and rig acceptance criteria.

9 Nov 2015

Lundin Petroleum commences Selada exploration well, offshore Malaysia

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that its wholly owned subsidiary Lundin Malaysia BV (Lundin Malaysia) has commenced drilling of the Selada-1 exploration well in Block PM308A, offshore Malaysia. The well will target hydrocarbons in Miocene aged sands and is located 14 km to the south of the Bertam field operated by Lundin Malaysia. The Selada-1 exploration well .... [+ read more] will be drilled with the West Prospero jack-up rig to a total depth of approximately 1,700 metres below mean sea level. The drilling of the well is expected to take approximately 30 days. Lundin Malaysia is the operator of and holds a 75 percent working interest in PM308A with PETRONAS Carigali Sdn Bhd holding a 25 percent working interest. Lundin Malaysia operates seven blocks in Malaysia, namely PM307, PM319, PM308A, PM308B, PM328, SB303 and SB307/308.

6 Nov 2015

Lundin Petroleum update on Neiden exploration well, Barents Sea South

Lundin Petroleum AB (Lundin Petroleum) announces that its wholly owned subsidiary Lundin Norway AS (Lundin Norway) has successfully drilled a section of the exploration well 7220/6-2 on the Neiden prospect in PL609. Drilling operations on exploration well 7220/6-2 on the Neiden prospect have now been temporarily suspended due to winter restrictions on the use of the Island Innovator drilling rig in .... [+ read more] the Barents Sea South. Operations to complete the well are expected to resume next year. Lundin Norway is the operator of and holds a 40 percent working interest in PL609. Partners are DEA Norge AS and Idemitsu Petroleum Norge AS with a 30 percent working interest each.

5 Nov 2015

SNE-2: First appraisal well starts drilling offshore Senegal

The first appraisal well to be drilled on the SNE oil field located 100km offshore Senegal has been spudded. The SNE-2 well will be drilled in approximately 1,100 metres of water and drilled to a TDVSS (total vertical depth subsea) of approximately 2,770 metres before an evaluation program including logging, coring and flow testing is undertaken. Three evaluation wells, SNE-2, SNE-3 .... [+ read more] and BEL-1, will be drilled back to back in a program that is estimated to be completed in mid-2016. Both SNE-2 and SNE-3 appraisal wells will be logged, cored and flow tested. The aim of the appraisal program is to progress towards proving a minimum economic field size for the SNE discovery, which FAR estimates to be approximately 200 million barrels of oil. In addition, the BEL-1 well will drill the Bellatrix exploration prospect which will evaluate the untested Buried Hills play. BEL1 will also appraise the northern portion of the SNE oil field (refer Figures 1, 2). For reasons of operational efficiency, the top hole of SNE-3 was drilled prior to the spud of SNE-2 (to a depth of 1,750 metres) by the Ocean Rig Athena (refer ASX announcement 2 Nov 2015). Drilling of the SNE-2 well is expected to take approximately 5 weeks after which the logging and flow testing program will commence. On completion of the operations on SNE-2, SNE-3 will be re-entered and drilling and evaluation will be carried out on SNE-3 before commencement of the BEL-1 well. FAR and its joint venture partners will be operating a tight hole policy, and therefore FAR does not anticipate making any further announcements regarding the drilling program until the SNE-2 well has reached TDVSS.

3 Nov 2015

Blink well results

Faroe Petroleum, the independent oil and gas company focusing principally on exploration, appraisal and production opportunities in Norway and the UK, announces the results of the Blink exploration well in the Norwegian Sea (Faroe 25%). The objective of well 6406/12-5 S was to test the hydrocarbon potential of the Upper Jurassic reservoirs analogous to the Pil, Bue, Boomerang and Draugen field .... [+ read more] reservoirs. The well encountered a 557 metre gross section of Upper Jurassic sandstone following a technical sidetrack (6406/12-5 S T2). The well reached a total vertical depth of 3,710 metres below sea level and preliminary analysis from wireline logs, pressure and fluid sampling shows that the well encountered clean water-wet sandstones with good reservoir properties but with no indications of hydrocarbons. The 6406/12-5 S (Blink) well was drilled on the Halten Terrace, approximately 27 kilometres south west of the Njord field and five kilometres north east of the Pil discovery well. Well 6406/12-5 S followed on directly from the Boomerang exploration well which encountered a 26 metre gross Upper Jurassic intra-Spekk/Rogn sandstone containing estimated recoverable resources of between 13 and 31 million barrels of oil equivalent. Graham Stewart, Chief Executive of Faroe Petroleum commented: “Whilst the results of the Blink well, the last in this year’s campaign, are disappointing we look forward to advancing the options for monetising the significant combined Pil, Bue and Boomerang discoveries, on which the Blink well result has no bearing. “The Company continues to perform very well despite continuing low oil prices, with low operating costs, a good cash position and strong production rates. Faroe’s consistent strategic focus and prudent approach to financial management have ensured that we have a strong balance sheet and are well placed to progress our portfolio work programme and take advantage of further good quality emerging opportunities.”

3 Nov 2015

Seafox Ahmed

Seafox Ahmed is a three-legged, self-elevating jack-up unit for accommodation and offshore support services built in Vicksburg, Mississippi (USA), by Marathon LeTourneau. She was originally converted to a jack-up ASV in 1993 by Lamprell, in Sharjah, UAE. The last upgraded took place in 2007 and the next Special Survey will take place end of 2015. The maximum Person on Board .... [+ read more] (POB) capacity for this vessel is 300 in her current configuration (250 Client POB). Seafox Ahmed has a maximum water depth operating capability of 300 feet. She has three cranes, with a maximum lift of 110 MT. She also has 600 m² of free deck space. The high quality of life on board is thanks to various leisure facilities and additional health and well-being amenities.

2 Nov 2015

Contract Extension Agreed on the Ocean Courage

As announced in Diamond Offshore’s November fleet status report, the company has agreed to terminate the drilling contracts on the Ocean Clipper and Ocean Alliance early and add 875 days to the end of the current term of the Ocean Courage at the rate of US$380,000 per day. The agreement has now been approved by Petrobras. Diamond Offshore is now finalising .... [+ read more] the amendments to the drilling contracts.

2 Nov 2015

Ocean Clipper to be Retired

According to Diamond Offshore's fleet status report, the Ocean Clipper has been retired and is now preparing for exportation from Brazil. The asset is due to be scrapped. The remaining contract term on the Ocean Clipper has been added to the Ocean Courage. .... [+ read more]

2 Nov 2015

Cancellation of the Songa Trym drilling contract

Songa Offshore SE (the "Company") has received a notice of cancellation of the drilling contract with Statoil for Songa Trym when the current well, Tarvos, is completed around 12 November 2015. The Company will receive a contractual cancellation fee based on the current full day rate of USD 377,000 and the contractual end date early March 2016. The rig .... [+ read more] will after the Tarvos well be stacked while marketed for new employment.

2 Nov 2015

Results of G4/50-10 Exploration Well

Ophir announces that it has completed operations on the G4/50-10 exploration well that was testing the Soy Siam prospect. The well reached a total depth of 1,627 metres (True Vertical Depth Sub-Sea) and encountered the primary Miocene reservoir targets on prognosis in terms of both reservoir quality and depth. However, all reservoirs were dry and no hydrocarbon shows were encountered. The .... [+ read more] well has therefore been plugged and abandoned as a dry hole. Preliminary well failure analysis suggests that the structure had no access to charge, which was identified pre-drill as one of the key risks. The rig will now move to drill the Parichat South West prospect. This well is independent of Soy Siam as it is testing a different petroleum system. The Parichat complex is a cluster of four fault blocks located 30 km south of the Bualuang field that have potentially been charged from deeper in the South Western Sub-Basin. Each fault block has multiple stacked, Miocene and Oligocene reservoir targets. The South West fault block is the initial target with a mean prospective resource of 25 MMbo and a 32% chance of success. If successful, the Parichat South East fault block would form an immediate follow on location.

2 Nov 2015

Drilling commences offshore Senegal

Drilling has started on the appraisal program to evaluate the world class SNE oil discovery offshore Senegal. The three wells SNE-2, SNE-3 and BEL-1 will be drilled back to back in a program that is estimated to be completed in mid-2016. Both SNE-2 and SNE-3 appraisal wells will be logged, cored and flow tested. The aim of the appraisal program is .... [+ read more] to progress towards proving a minimum economic field size for the SNE discovery, which FAR estimates to be approximately 200 million barrels of oil. In addition the BEL-1 well will also evaluate the Bellatrix prospect which lies on the untested Buried Hills exploration play (refer Figures 1, 2). For reasons of operational efficiency, the top hole of SNE-3 will be drilled first by the Ocean Rig Athena. The rig will be then be mobilised to the SNE-2 well location where SNE-2 will then be drilled to total depth (TD). Operations on the top hole of the SNE-3 well and drilling to total depth (TD) on the SNE-2 well are expected to last approximately 6 weeks after which the coring, logging and flow testing program will commence on SNE-2. On completion of the operations on SNE-2, SNE-3 will be re-entered and drilling and evaluation will be carried out before commencement of the BEL-1 well.

30 Oct 2015

Pacific Drilling Rescinds Pacific Zonda Construction Contract

Pacific Drilling S.A. announced that it has exercised its right to rescind the construction contract for ultra-deepwater drillship Pacific Zonda due to the failure by Samsung Heavy Industries (SHI) to timely deliver a vessel that substantially meets the criteria required for completion of the vessel in accordance with the construction contract and its specifications. Pacific Drilling made advance payments totaling approximately .... [+ read more] $181.1 million under the contract, and will be seeking a refund of the installment payments.

29 Oct 2015

53/02-01 Humpback exploration well results

Falkland Oil and Gas Limited (AIM:FOGL), the exploration company focused on its extensive licence areas to the North, South and East of the Falkland Islands, announces the results from the 53/02-01 Humpback exploration well and also, notes the announcement from the Operator, Noble Energy made at 20:30 on 28 October 2015. The Humpback well was drilled to a total depth .... [+ read more] of 5,136 meters (measured depth). The well encountered non-commercial quantities of oil and gas within a number of sandstone intervals, including the main APX-200 target. All of the pre-drill targets were penetrated close to prognosis in the well. An additional 25 meters of sandstone was encountered below the APX-200 bringing the total in the well to 65 meters. The deeper sandstones, exhibit only moderate porosity (10% to 15%) and low hydrocarbon saturations. For a number of operational reasons, it was not possible to obtain fluid samples from any of the hydrocarbon bearing zones in the well. FOGL will now evaluate these results in more detail and assess the impact on the prospectivity of the Diomedea fan complex and the rest of the southern licences. The results do however demonstrate a working hydrocarbon system and Humpback was only one of a number of geological plays within the Fitzroy sub-basin. Importantly the results will allow calibration of the 3D seismic data and this may facilitate the mapping of higher quality sands elsewhere within the large area covered by 3D seismic. Once operations have been completed on Humpback, the Eirik Raude rig will return to the North Falklands Basin to drill a second well on the Elaine/Isobel fan complex. The Elaine/Isobel fan complex, based on the operator’s estimates, has multiple reservoir targets and gross mean un-risked resources of 400 million barrels of oil. A further announcement will be made on the commencement of this well.

28 Oct 2015

Atwood Oceanics Announces Contract Extension for the Atwood Orca

Atwood Oceanics, Inc. (NYSE: ATW) announced today that one of its subsidiaries had agreed to a nine-month extension and rate adjustment to its existing contract with Mubadala Petroleum (SE Asia) Limited (“Mubadala Petroleum”) for the ultrapremium jackup, the Atwood Orca, effective November 1, 2015. The Atwood Orca commenced its drilling services contract with Mubadala Petroleum for operations offshore Thailand on April .... [+ read more] 29, 2013. The extension continues the drilling services until the new contract end date of October 28, 2016. Additionally, the agreement adjusts the operating day rate to approximately $85,000 from November 1, 2015 until the new contract end date.

28 Oct 2015

Primeline Completes LS23-1-1 Well and Will Continue with Drilling of LS30-3-1 Well

Primeline Energy Holdings Inc. (“Primeline” or the “Company”) (TSXV: PEH) today announces that it has completed the drilling operations of the LS23-1-1 well and will now continue with the exploration drilling programme for the LS30-3-1 well. The LS23-1-1 well was spudded on September 23 and reached total depth (TD) of 2,666m on October 21, 2015 and wireline logging data was .... [+ read more] subsequently acquired. The well encountered sandstone units of Paleocene and early Cretaceous age, drilling through the geological sequence as anticipated and finished in basement rock. It discovered several zones of gas bearing sandstone and evaluation of logging data indicated total cumulative net pay thickness of 14 metres. The LS23-1 prospect is a technical discovery of hydrocarbon but not likely to be a commercial discovery. Therefore Primeline has plugged and abandoned the well and will proceed with the drilling of the LS30-3-1 well on the basis of the agreed two well work programme. LS30-3-1 is located approximately 20km north of the LS36-1 gasfield platform and is targeting a large channel sand prospect. The prospect was originally mapped in 2009/2010 and refined during the 2014/2015 evaluation. The planned TD of the well is 1,800m, targeting the same reservoir as that of the LS36-1 gasfield. The drilling rig HYSY941 is currently conducting the final operations for the LS23-1-1 well. Once completed, Primeline’s contractor China Oilfield Service Ltd plans to mobilise the rig to the LS30-3-1 location subject to weather and sea conditions, allowance for necessary equipment maintenance and preparation and approval of the operation licence. A separate announcement will be made when the drilling operation of LS30-3-1 commences.

28 Oct 2015

Keppel FELS delivers eighth rig of the year safely and on time

Keppel FELS, a wholly owned subsidiary of Keppel Offshore & Marine (Keppel O&M) has delivered ARABDRILL 70, a KFELS B Class jackup rig, to Arabian Drilling Company (ADC). It was completed three days ahead of schedule, on budget and with a perfect safety record. ARABDRILL 70 is the fourth KFELS B Class jackup rig to work for ADC. .... [+ read more]

28 Oct 2015

Keppel FELS delivers eighth rig of the year safely and on time

Keppel FELS, a wholly owned subsidiary of Keppel Offshore & Marine (Keppel O&M) has delivered ARABDRILL 70, a KFELS B Class jackup rig, to Arabian Drilling Company (ADC). It was completed three days ahead of schedule, on budget and with a perfect safety record. ARABDRILL 70 is the fourth KFELS B Class jackup rig to work for ADC. .... [+ read more]

27 Oct 2015

Bollsta Dolphin - Termination of Construction Contract and Drilling Contract

Bollsta Dolphin Pte. Limited (“Bollsta”), a wholly owned subsidiary of Fred. Olsen Energy ASA (“FOE”), has notified Hyundai Heavy Industries Co., Ltd. Korea (“HHI”) that it has exercised its contractual termination right under a newbuilding contract between HHI and Bollsta for the construction of a semi-submersible drilling rig (the “Rig”) as a result of delay in delivery of the Rig. .... [+ read more] The rig construction contract provides that on termination Bollsta will be entitled to a refund of the first instalment paid to HHI of USD 186,390,240 plus accrued interest. The Rig was on 26 October 2012 contracted by Dolphin Drilling Ltd., another wholly owned subsidiary of FOE (“DDL”), to Chevron North Sea Limited (“CNSL”). CNSL (as operator on behalf of its coventurers) and DDL have mutually terminated the drilling contract on amicable terms.

26 Oct 2015

Transocean Ltd. Announces Ultra-Deepwater Drillship Delivery Delays For Deepwater Pontus, Deepwater Poseidon

Transocean Ltd. (NYSE: RIG) (SIX: RIGN) announced today a mutual agreement with its customer, Shell EP Wells Equipment Wells Services B.V. (Shell), and the shipyard, Daewoo Shipbuilding & Marine Engineering Co. (DSME), to delay the operating and delivery contracts of two newbuild ultra-deepwater drillships - the Deepwater Pontus and the Deepwater Poseidon - by 12 months each. The delay has .... [+ read more] no impact on the duration or dayrate of the original 10-year operating contracts for each of the two newbuild ultra-deepwater drillships. Parties will be compensated for the postponement. The specific terms are not disclosed. The delivery and operating agreements for Shell's two other contracted Transocean newbuild, ultra-deepwater drillships, the Deepwater Thalassa and Deepwater Proteus, are not impacted by this agreement. "We are pleased that the strength of our relationships with both Shell and DSME has enabled us to reach this mutual agreement," said Transocean President and Chief Executive Officer Jeremy Thigpen. "We are excited by the progress that we have jointly made with Shell on all four high-specification, ultra-deepwater drillships, including the Deepwater Thalassa, which was delivered this September, and the Deepwater Proteus, which is scheduled for delivery this December."

26 Oct 2015

Sea Lion-1 Drilling Commenced

3D Oil Limited (ASX: TDO) is pleased to announce that the Sea Lion-1 exploration well commenced drilling operations today at 12:45 pm Melbourne time. The well is being drilled by the West Telesto jack up rig which arrived on site 22 October 2015. Sea Lion is located in offshore Gippsland Basin permit VIC/P57 where 3D Oil has a 24.9% interest in .... [+ read more] Vic/P57 while the company’s share of Sea Lion-1 well costs is being carried up to the extent of US$7.5 million as part of an agreement with joint venture operator Carnarvon Hibiscus Pty Ltd (‘CHPL’) the wholly owned subsidiary of Hibiscus Petroleum. The planned total depth of the Sea Lion-1 well is 1800m and operations are scheduled to take a total of approximately 3 - 4 weeks. Sea Lion is considered highly prospective as it is on a proven oil-producing trend, and represents one of the last undrilled 4-way dip closures at the prolific ‘Top Latrobe’ level in the Gippsland Basin. The combination of prominent mapped depth structure and the likely presence of thick high quality reservoir sands overlain by the regional seal provides the ingredients of a high quality target. An independent report has assessed the Sea Lion most likely (P50) Prospective Resource at 11.0MMbbl of oil (combined probabilistic estimate for the three main target levels).

26 Oct 2015

Lundin Petroleum completes the Mengkuang-1 exploration well, offshore Malaysia

Lundin Petroleum AB (Lundin Petroleum) announces that its wholly owned subsidiary Lundin Malaysia BV (Lundin Malaysia) has made a small gas discovery with the Mengkuang-1 exploration well in license PM307, offshore Malaysia. The well targeted hydrocarbons in Miocene aged sands 75 km to the northwest of the Bertam field operated by Lundin Malaysia. Mengkuang-1 was drilled with the West Prospero jack-up .... [+ read more] rig to a total depth of 1,259 metres below mean sea level. The well encountered 9 metres of gas pay in the I-35 group Miocene channel sands. The well was plugged and abandoned. Lundin Malaysia holds 75 percent working interest in PM307. Partner is PETRONAS Carigali Sdn Bhd with 25 percent working interest. Lundin Malaysia operates six blocks in Malaysia, namely PM307, PM319, PM308A, PM308B, PM328 and SB307/308.

22 Oct 2015

Hyundai asks for more time and money to complete 'Bollsta Dolphin'

Bollsta Dolphin Pte. Ltd (“Bollsta”), a wholly owned subsidiary of Fred. Olsen Energy ASA (“FOE”), today received a notice of arbitration from Hyundai Heavy Industries Co. Ltd. (“HHI”). HHI alleges that it is entitled to an additional payment of about USD167 million and additional time to complete and deliver a Semi-Submersible Drilling Unit which is under construction by HHI pursuant to .... [+ read more] a newbuilding contract that was entered into between HHI and Bollsta in 2012. Reference in this regard is made to our previous announcement to the Oslo Stock Exchange on 25 May 2012. FOE believes that HHI claim’s is considered unfounded.

21 Oct 2015

Ophir Energy begins new exploration campaign in Thailand

Ophir Energy Plc (“Ophir”) has announced that it has commenced a two well exploration drilling program in Block G4/50, in the western Gulf of Thailand with the spud of G4/50-10 exploration well on the Soy Siam prospect. The G4/50 Block partly surrounds Ophir’s producing Bualuang oil field and spans a series of Tertiary aged sub-basins in the western Gulf of Thailand. .... [+ read more] The two well program will test whether there is a working hydrocarbon system in one of these, the presently undrilled South Western Sub-Basin. The main play risk is considered to be charge, specifically source distribution and maturity. The Soy Siam Prospect comprises a single fault block which has potentially been charged from both the Bualuang and South Western Sub-Basins. The G4/50-10 well is targeting Miocene sandstones that are the age equivalent of the producing reservoirs in the Bualuang oil field, located 15 km to the north. The Soy Siam Prospect has 25 MMbo of mean prospective resource and a 21% chance of success. On completion of the G4/50-10 well, the rig will move to drill the Parichat South West (SW) prospect. The Emerald Driller jackup rig is being used for the G4/50 drilling programme. The estimated cost of the two well program is USD18 million and it is expected to take approximately 50 days to complete.

19 Oct 2015

'Ocean Rig Athena' enroute to Senegal

FAR Limited (“FAR”) has announced that the Ocean Rig Athena drillship has commenced mobilisation from Luanda, Angola in preparation for the appraisal and exploration drilling program in FAR’s highly prospective blocks, offshore Senegal. The SNE discovery made in late 2014 will be appraised with the first two wells in the three well drilling program. The firm drilling program will include a .... [+ read more] coring and testing program, two appraisal wells for SNE (SNE-2 and SNE- 3) plus one shelf exploration well (BEL-1) to further evaluate the shelf area prospectivity. The three wells will be drilled, logged, cored and tested in a program expected to be completed by mid-2016. BEL-1 will be the first exploration well to be drilled in the blocks following the discoveries in the FAN-1 and SNE- 1 wells.

16 Oct 2015

Lundin spuds exploration well at Rolvsnes prospect

Lundin Petroleum AB (“Lundin Petroleum”) is pleased to announce that its wholly owned subsidiary Lundin Norway AS (“Lundin Norway”) has commenced drilling of exploration well 16/1-25 S on the Rolvsnes prospect in PL338C. The well is located approximately 6 km south of the Edvard Grieg field in the North Sea sector of the Norwegian Continental Shelf (NCS). Well 16/1-25 S will .... [+ read more] explore the Rolvsnes area, located between the Edvard Grieg field and the Luno II discovery. The main objective of well 16/1-25 S is to test the hydrocarbon potential in thin Jurassic/Cretaceous sandstone reservoir overlying porous fractured basement. Lundin Petroleum estimates the Rolvsnes prospect to contain gross unrisked prospective resources of 107 million barrels of oil equivalents (MMboe). The planned total depth is approximately 2,275 metres below mean sea level and the well will be drilled with the semi-submersible drilling unit Bredford Dolphin. The drilling operation is expected to take approximately 45 days. Lundin Norway is the operator of PL338C with 50 percent working interest. The partners are Lime Petroleum Norway AS with 30 percent and OMV (Norge) AS with 20 percent working interest.

16 Oct 2015

North Dragon Sea Trial

According to a press release on North Sea Rigs website, the North Dragon semisub successfully completed a sea trial on Friday 16 October 2015. .... [+ read more]

16 Oct 2015

Lundin Petroleum spuds exploration well on the Rolvsnes prospect, south of the Edvard Grieg field, offshore Norway

Lundin Petroleum AB (Lundin Petroleum) is pleased to announce that its wholly owned subsidiary Lundin Norway AS (Lundin Norway) has commenced drilling of exploration well 16/1-25 S on the Rolvsnes prospect in PL338C. The well is located approximately 6 km south of the Edvard Grieg field in the North Sea sector of the Norwegian Continental Shelf (NCS). Well 16/1-25 S will .... [+ read more] explore the Rolvsnes area, located between the Edvard Grieg field and the Luno II discovery. The main objective of well 16/1-25 S is to test the hydrocarbon potential in thin Jurassic/Cretaceous sandstone reservoir overlying porous fractured basement. Lundin Petroleum estimates the Rolvsnes prospect to contain gross unrisked prospective resources of 107 million barrels of oil equivalents (MMboe). The planned total depth is approximately 2,275 metres below mean sea level and the well will be drilled with the semi-submersible drilling unit Bredford Dolphin. The drilling operation is expected to take approximately 45 days. Lundin Norway is the operator of PL338C with 50 percent working interest. The partners are Lime Petroleum Norway AS with 30 percent and OMV (Norge) AS with 20 percent working interest.

16 Oct 2015

Panoro Energy Provides Operational Update

The Aje-5 production well located on the OML 113 license, offshore Nigeria, has been successfully completed and the reservoir has been perforated in the Upper and Lower Cenomanian Oil bearing zones. The subsea tree has been installed and the well has been suspended ready for connection to the oil production facilities prior to commencement of production. The Saipem Scarabeo 3 .... [+ read more] semi-submersible drilling rig has been moved to re-enter the existing Aje-4 well for completion as a second Cenomanian production well. All key equipment related to the Aje oilfield development has now been delivered to Lagos, including the FPSO moorings and turret buoy, the production manifold, the umbilical termination assembly, and the umbilicals and flowlines. In addition, the ongoing refurbishment of the Front Puffin FSPO is on schedule and it is anticipated that the vessel will sail from Singapore approximately six weeks prior to its installation date. Panoro currently estimates the project timing and costs to be largely on track, although for planning purposes, the Company is now projecting that first oil should take place towards the end of January 2016.

16 Oct 2015

Sea Lion-1 set to spud

3D Oil Limited (ASX: TDO) is pleased to announce that the Sea Lion-1 exploration well is expected to spud late next week with the West Telesto jack up rig now mobilised from its previous assignment. 3D Oil has a 24.9% interest in the Vic/P57 exploration permit, in which the well is located, while the company’s share of well costs is being .... [+ read more] carried up to the extent of US$7.5 million as part of an agreement with joint venture operator Carnarvon Hibiscus Pty Ltd (‘CHPL’) the wholly owned subsidiary of Hibiscus Petroleum. The planned Total Depth of the well is programmed for 1800m and scheduled to take approximately 3 weeks. Sea Lion is considered highly prospective as it is on a proven oil-producing trend, and represents one of the last undrilled 4-way dip closures at the prolific ‘Top Latrobe’ level in the Gippsland Basin. The combination of prominent mapped depth structure and the likely presence of thick high quality reservoir sands overlain by the regional seal provides the ingredients of a high quality target. An independent report has assessed the Sea Lion most likely (P50) Prospective Resource at 11.0MMbbl of oil (combined probabilistic estimate for the three main target levels).

15 Oct 2015

Cosco agrees to further delay in delivery of 'Sevan Developer'

Sevan Drilling Limited (“Sevan Drilling”) has made reference to a press release dated 16th October 2014 regarding delivery of the Sevan Developer semisub. Sevan Drilling and Cosco have agreed to delay the end of the first deferral period from 15th October 2015 to 1st November 2015 in order to continue negotiations of the first six-month option period. .... [+ read more]

14 Oct 2015

'Ocean Rig Athena' to mobilise to Senegal in the coming days

FAR Limited (“FAR”) and its Senegal joint venture partners have executed contracts for the use of the Ocean Rig Athena drillship for a drilling program in FAR’s highly prospective offshore Senegal Blocks starting in the coming weeks. The Ocean Rig Athena is under long term contract with ConocoPhillips and the ConocoPhillips drilling organisation will play a key role in project managing .... [+ read more] the drilling program. The drillship is currently in Angola and FAR expects it will commence mobilisation to Senegal in the next few days. The firm drilling program includes three wells including two appraisal wells on the world class SNE-1 oil discovery that will include a coring and testing program, plus one shelf exploration well to further evaluate the shelf area prospectivity. This drilling, logging, coring and testing program is expected to be completed by mid- 2016. The first two wells (SNE-2 and SNE-3) will be drilled to appraise the SNE field and are aimed at progressing towards proving the threshold economic field size which FAR estimates is in the order of 200 mmbbls for a foundation project. The third well (BEL-1) in the drilling program will be the first exploration well to be drilled in the blocks following the discoveries in the FAN-1 and SNE-1 wells. This well will be aimed at building the resource base within tie-back range of a possible future hub development over the SNE field. It will be drilled into the Bellatrix Prospect which has been mapped by FAR to contain 168 mmbbls of oil on a gross, unrisked, prospective resource basis with 25 mmbbls net to FAR. The day rate for drilling for the Senegal joint venture has been adjusted downwards to reflect prevailing market conditions, where day rates have dropped by up to 50% for deep water drilling units offshore Africa. These reduced rates are expected to allow the drilling and testing program to be completed for a heavily reduced cost in comparison to what was envisaged 12 months ago under a higher oil price environment.

14 Oct 2015

Lukoil announces new discovery in Romania

PJSC LUKOIL (“Lukoil) has announced the completion of drilling operations at the Lira-1X exploration well location and the discovery of a gas field in the Lira offshore structure, which is located at the Trident block (EX-30) in the deep-sea Romanian offshore. Exploration on the EX-30 block is conducted by LUKOIL Overseas Atash BV (100-% subsidiary of Lukoil) within the framework of .... [+ read more] the Concession Agreement with the Government of Romania of 2011. Currently Lukoil’s share in the project is 72%, while PanAtlantic Petroleum Ltd owns 18% and Societatea Nationale de Gaze Naturale Romgaz SA owns 10%. The Lira-1X well is located at a distance of about 170 km (90 miles) from the coast, where the depth of the sea is about 700 meters. The well was drilled to a depth of 2,700 meters (8,858 feet) from the semisub drilling rig Development Driller II. The well was temporarily abandoned for further evaluation of the Lira gas discovery. According to preliminary results of the analysis of drilling data and geophysical exploration, the Lira-1X delivered a productive interval with an effective gas-saturated thickness of 46 meters. The success of the Lira-1X well will reduce the risk for further exploration on a series of prospective sites with significant potential reserves, located both close to the Lira structure and in other parts of the block. The program of future works planned for 2016 includes drilling an exploration well at the Lira and the reprocessing of seismic data to confirm the size of the discovery and precise assessment of its potential hydrocarbon reserves.

13 Oct 2015

Repsol drills duster in Norwegian Sea

Repsol Norge AS, operator of production licence 642, is in the process of concluding the drilling of wildcat well 6306/5-2. The well is dry. The well was drilled about 65 kilometres southwest of the Njord field and 35 kilometres southeast of the 6406/12-3 S and A discoveries (Pil and Bue) in the Norwegian Sea. The objective of the well was to .... [+ read more] prove petroleum in Upper Jurassic reservoir rocks (the Rogn formation) and Upper Jurassic reservoir rocks (the Melke formation). Well 6306/5-2 encountered an approx. 12-metre thick sandstone layer in the Rogn formation, with good reservoir quality. The well also encountered 247 metres of sandstone in the Melke formation with moderate reservoir quality. The well is dry. Data acquisition and sampling have been carried out. This is the first exploration well in production licence 642, which was awarded in APA 2011. Well 6306/5-2 was drilled to a vertical depth of 3192 metres below the sea surface and was terminated in the Melke formation in the Upper Jurassic. Water depth at the site is 226 metres. The well will now be permanently plugged and abandoned. Well 6306/5-2 was drilled by the Bredford Dolphin drilling facility, which will now proceed to drill wildcat well 16/1-25 S in production licence 338 C in the North Sea, where Lundin Norway AS is the operator.

12 Oct 2015

Mærsk Deliverer back on the job

Mærsk Deliverer has successfully completed her five-yearly special periodic survey (SPS) yard stay ahead of time. The scope for the yard stay was extensive, with more than 210 job packages and 584 work orders that needed to be completed within 35 days along keyside - which makes for a very efficient and successful SPS yard stay. The scope, among others, involved .... [+ read more] Class recertification, BOP upgrade & overhaul and overhaul of the entire drilling package. Deliverer has now successfully resumed drilling operations offshore Angola. Ahead of the Mærsk Deliverer yard stay, a tremendous amount of planning and scheduling has been carried out. This was done across different departments and teams both onshore and offshore, and according to Project Manager Morten Svanholt, part of the success is due to the increased focus on teamwork. “We could not have carried out such a successful yard stay without involving the many different stakeholders from across the company. Knowledge sharing and teamwork have been essential elements in planning this project, and we will put even more emphasis on this in future projects”. CTO in Maersk Drilling, Frederik Smidth, agrees, and stresses that this achievement is no small matter to him either. “I am really proud of the team of both offshore and onshore colleagues, who have worked very hard to make this project such a success. The team has managed to complete more than 210 activities on board the Mærsk Deliverer over a very short period of time. Every minute counts in our line of business, and when we work together we can optimise the impact that these yard stays have.” says Frederik Smidth, Chief Technical Officer, Maersk Drilling. From the outset, planning has been a crucial part of the Mærsk Deliverer project and has contributed significantly to the success of the yard stay as a whole. Going forward, optimisation of the yard stay process will be a key focus area for Technical Organization and Operations in Maersk Drilling. “A yard stay equals time where the rig does not earn any money, but rather spend them instead. When we can optimise and make these yard stays more efficient, we can drive down the cost. The team has done a tremendous job in making this yard stay efficient, while still maintaining a safe environment for everyone working on the rig. That is no easy job – well done! This is a great start, but we will need to work even harder to limit the impact that yard stays have on our daily operations,” says Claus Bachmann, Asset Manager for Deepwater in Maersk Drilling.

12 Oct 2015

EDC announces termination of 'Saturn' jackup contract

Eurasia Drilling Company Limited ("EDC") has announced that it received a letter of early termination of the contract for its Saturn jackup rig effective from October 8th 2015. The current contract was due to expire on 8th January 2016 and the early termination fee consists of 100% of contract rate for 30 days from effective date followed by 85% of contract .... [+ read more] rate for the remainder of the term (or 62 days).

10 Oct 2015

Uxpanapa hull successfully launched

The fifth jackup rig that Keppel AmFELS is constructing for Perforadora Central, Uxpanapa, reached a double milestone on 22 September 2015. Its hull was successfully launched into the sea and it also celebrated two million man hours worked without lost time incidents. In recognition of the yard’s achievement, PerforadoraCentral presented the project team with a plaque and safety bonus of US .... [+ read more] $30,000. Mr Ricardo Cortinas, Vice President, Offshore Drilling Operations, Central Panuco (Perforadora Central) said, “It is always very exciting to see the successful launching of a rig. Central Panuco is very pleased with the on time production schedule of Uxpanapa and would like to congratulate the dedicated employees at Keppel AmFELS for achieving two million man-hours without any lost time incidents.”

9 Oct 2015

Coastal Contracts enter into litigation regarding delivery of jackup

Coastal has announced that its subsidiary, Thaumas Marine Ltd ("TML"), a party to a shipbuilding contract (“SBC”) with Yantai CIMC Raffles Offshore Limited (“Builder”) and Dynamic Driller Limited (“Co-Builder”), has on the 9th of October 2015 filed a Notice of Arbitration with the Singapore International Arbitration Centre (“SIAC”) against the Builder and Co-Builder to refer a dispute to arbitration, thereby commencing .... [+ read more] arbitration proceedings against the same. Pursuant to the SBC (and the relevant Annexes, Exhibits, Modifications, Additions, Supplemental(s), Supplementary Agreements, Memorandums and Addendums), the Builder and the Co-Builder are to construct and deliver to TML one (1) unit brand new JU 2000E F&G Design Jack-Up Drilling Rig (“Vessel”) within the Delivery Date of 30th April 2015, or no later than the Cancellation Date of 30th June 2015. Should the Builder and Co-Builder not be able to deliver the Vessel on or before 30th June 2015, the Builder and Co-Builder would be liable to TML for liquidated damages of United States Dollars Fifty Thousand (USD 50,000.00) only per day, up to a maximum of United States Dollars Five Million (USD 5,000,000.00) only. The Vessel was accepted to be technically ready for delivery on 11 September 2015, seventy-three (73) days after the Cancellation Date. Accordingly, the Builder and Co-Builder are liable to TML for liquidated damages to the amount of United States Dollars Three Million and Six Hundred and Fifty Thousand (USD 3,650,000.00) and any applicable interest.

9 Oct 2015

Successful visit to the shipyard

Today the drilling rig Deepsea Bergen leaves the shipyard in Haugesund after completing its 5-year classification. The assignment has been performed within the agreed timeframe. On behalf of Odfjell Drilling, Aibel has carried out work associated with the 5-year classification of the drilling rig. The work comprised inspections and modifications related to structure and pipes, among other things. Aibel's Project Manager .... [+ read more] Jarle Toft explains that many activities had to be carried out in narrow areas on board. There was also a need for extensive cleaning prior to the work commencing. "We have been working to a tight schedule and have achieved a lot in a short period of time. Handover took place at the end of September, and our part of the work took 21 days," the Project Manager says. He also notes that there have not been any serious incidents, and that employees have had an excellent focus on HSE.

8 Oct 2015

Lundin receives consent for exploration drilling in the Barents Sea

Lundin Norway AS (Lundin) is the operator for production licence 708 and has received consent to drill exploration well 7130/4-1 in the Barents Sea. Drilling is scheduled to begin in November 2015 and estimated to last 56 days, depending on whether a discovery is made. Drilling is to be carried out using Transocean Arctic, a semi-submersible drilling facility owned and .... [+ read more] operated by Transocean. It was built by Mitsubishi Heavy Industries in Japan in 1987, and substantially upgraded in 2004. It was issued with an Acknowledgement of Compliance (AoC) by the PSA in July 2004. The PSA has now granted Lundin consent for exploration drilling.

8 Oct 2015

Audit of Deepsea Bergen

On 21 and 22 September 2015, the PSA carried out an audit of Deepsea Bergen while the facility was at the Aibel Haugesund yard. The audit was focused on Odfjell Drilling's management of hull inspection, verification of the lifetime of structures and findings made during the layover. This audit was in continuation of the audit's first part carried out in .... [+ read more] June 2015. The purpose of the audit was to see how, as the rig owner, Odfjell Drilling was ensuring the safety of ageing facilities that have received an Acknowledgement of Compliance (AoC), in terms of ageing mechanisms and modifications, and how learning from identified ageing mechanisms and factors in previous incidents are used with respect to the structural safety of Deepsea Bergen. No non-conformities or improvement points were identified during this audit.

8 Oct 2015

Oceam Rig releases update on current fleet status

Ocean Rig UDW Inc. (“Ocean Rig”) has released an update to the current status of the company’s offshore rig fleet. In the release Ocean Rig announced that the Ocean Rig Skyros commenced its new six year contract with Total in Angola on the 1st October 2015 as well as giving updates as to the Leiv Eiriksson, Eirik Raude and Ocean Rig .... [+ read more] Olympia units. With regards to the latter three units, Ocean Rig announced that upon completion of their current contracts the company will look to cold stack the units if no new contracts can be secured and in the cases of the Eirik Raude and Leiv Eiriksson semisubs the company may choose to dispose of the assets through scrapping. Meanwhile the company also announced that on the 25th September it received a notice from Petrobras of a material breach under the contract for the Ocean Rig Mylos drillship which would enable Petrobras to terminate the contract if the breach is not remedied within 75 days. Ocean Rig announced that it intends to defend its rights under the contract.

7 Oct 2015

Lundin spuds Neiden prospect with Island Innovator

Lundin Petroleum AB (“Lundin Petroleum”) is pleased to announce that its wholly owned subsidiary Lundin Norway AS (“Lundin Norway”) has commenced drilling of exploration well 7220/6-2 in PL609. The Neiden prospect is located in the northern part of PL609, some 60 km northeast of the Alta discovery and approximately 200 km from the Norwegian coastline. Lundin Petroleum estimates the Neiden prospect .... [+ read more] to have the potential to contain unrisked, gross prospective resources of 204 million barrels of oil equivalents. The planned total depth is approximately 1,350 metres below mean sea level and the well is being drilled using the drilling rig Island Innovator. Drilling is expected to take approximately 40 days. Lundin Norway holds 40 percent working interest in PL609. Partners are DEA Norge AS and Idemitsu Petroleum Norge AS with 30 percent working interest each.

7 Oct 2015

Energy Drilling one step closer to securing contract for 'Edrill-2'

Energy Drilling Pte. Ltd. (“Energy Drilling”) is one step closer to securing a firm contract for its newbuild Edrill-2 tender rig following the announcement that the company has been issued a Letter of Intent to Award (LOI) by PTT Exploration & Production International (“PTTEPI”). PTTEPI intends to contract the unit for a firm 18-month period with options to extend the contract .... [+ read more] by up to 30 months to perform drilling operations on the Zawtika Development Drilling Campaign (Phase 1B + Infield Phase 1A + Phase 1C). The program consists of around 67 wells to be drilled from ten wellhead platforms in water depths of up to 160m. Commencement date is set for mid-December 2015 with EDrill-2 currently undertaking pre-mobilization inspections and third party equipment installations. Marcus Chew – CEO of Energy Drilling commented that, “We’re pleased to extend our relationship with premium client PTTEP and are eager to demonstrate our tender barge’s superior value creation potential to MOGE in Myanmar.”

7 Oct 2015

Ocean Rig Announces Fleet Update

The Eirik Raude is currently completing its third well in a six-well program in the Falklands and is now expected to remain employed in the Falkland Islands into January of 2016. Currently, there are no further prospects of employment for the rig in the Falkland Islands and if no employment is found the rig will be cold stacked and the Company .... [+ read more] will consider all its options including disposing or scrapping the unit.

7 Oct 2015

Ocean Rig Announces Fleet Update

The Leiv Eiriksson is in the process of completing its current well in Norway. As of the date of this press release, there is no further program for the unit under its current contract which is expected to expire in March 2016. Currently, there are few further prospects of employment for the rig and if no employment is found the rig .... [+ read more] will be cold stacked and the Company will consider all its options including disposing or scrapping the unit.

7 Oct 2015

Ocean Rig Announces Fleet Update

The Ocean Rig Olympia has successfully started its new contract in Angola as of August 15, 2015. The rig is expected to move to the Ivory Coast for one well in the fourth quarter of 2015 and return to Angola to complete its remaining contract until June 2016. Currently, there are no prospects for further employment and if no employment is .... [+ read more] found the rig will be cold stacked and the respective SPS will be postponed.

5 Oct 2015

Perisai delays delivery of second jackup rig

Perisai Petroleum Teknologi BHD (“Perisai”) has announced that the company intends to delay the delivery of its second jackup rig ‘Perisai Pacific 102’ until the 31st March 2016. The unit was originally intended to be delivered on 30th April 2015, however, the delivery date is now revised to a date no later than 31st March 2016. The agreement was reached between .... [+ read more] Perisai and PPL Shipyard Pte Ltd.

2 Oct 2015

Lundin spuds Mengkuang-1 well in Malaysia

Lundin Petroleum AB (“Lundin Petroleum”) is pleased to announce that its wholly owned subsidiary Lundin Malaysia BV (“Lundin Malaysia”) has resumed exploration drilling in Malaysia with the spud of Mengkuang-1 exploration well in license PM307, offshore Malaysia. The well will target hydrocarbons in Miocene aged sands 75 km to the northwest of the Bertam field operated by Lundin Malaysia. Mengkuang-1 will .... [+ read more] be drilled with the West Prospero jack-up rig to a total depth of approximately 1,300 metres below mean sea level. The drilling of the well is expected to take approximately 30 days. Lundin Malaysia holds 75 percent working interest in PM307. Partner is PETRONAS Carigali Sdn Bhd with 25 percent working interest. Lundin Malaysia operates six blocks in Malaysia, namely PM307, PM319, PM308A, PM308B, PM328 and SB307/308.

2 Oct 2015

Hess sublets 'Perisai Pacific 101' jackup in Malaysia

Perisai Petroleum Teknologi BHD (“Perisai”) has announced that the company’s Perisai Pacific 101 jackup rig currently on contract to Petronas Carigali Sdn Bhd (“Petronas”) is to be sublet to Hess Exploration and Production Malaysia B.V. (“Hess”) for a nine month period. The sublet commenced on 23rd September 2015 and is expected to continue for a nine-month period, with an additional one .... [+ read more] month option. At the end of the sublet the unit will return to operations for Petronas. The total contract value of the sublet with Hess is USD26.9 million.

1 Oct 2015

Statoil comes up dry with latest wildcat in Norway

Statoil Petroleum AS, operator of production licence 169, has concluded the drilling of wildcat well 25/11-28. The well is dry. The well was drilled 13 kilometres south of the Grane field in the North Sea. The objective of the well was to prove petroleum in Upper Jurassic reservoir rocks (the Draupne formation) and in the Permian (the Rotliegend group). The .... [+ read more] well encountered 22 metres of sandstone in the Upper Jurassic, of which 7.5 metres is of good reservoir quality. Reservoir rocks were not proven in the Permian. The well is dry. Extensive data acquisition and sampling have been carried out. This is the 15th exploration well in production licence 169. The well was drilled to a vertical depth of 2563 metres below the sea surface, and was terminated in basement rock. Water depth at the site is 118 metres. The well will now be permanently plugged and abandoned. The well was drilled by the Songa Trym drilling facility, which will now drill wildcat well 34/8-16 S in production licence 120 in the northern North Sea, where Statoil Petroleum AS is the operator.

1 Oct 2015

Maersk find at Tvillingen South is non-commercial

North Energy has announced a non-commercial gas/condensate discovery from the Tvillingen Sør exploration well in PL 510 in the Norwegian Sea. The main objective of well 6406/6-4S was to test the reservoir properties and hydrocarbon potential of the Middle to Lower Jurassic sandstones on the Tvillingen Sør horst structure. The well encountered a hydrocarbon column of up to 30 metres in .... [+ read more] Garn Formation sandstones with good reservoir quality. The deeper reservoir targets showed high reservoir quality, but were water wet. The well was not formation tested, but data acquisition and sampling were carried out. Maersk Oil Norge AS is the operator of PL 510. Well 6406/6-4S was drilled to a total depth of 4,484 metres in the Tilje Formation by the Leiv Eiriksson rig. North Energy ASA holds a 20 per cent working interest in PL 510. Maersk Oil Norge AS holds 50 per cent and Edison Norge AS holds 30 per cent.

1 Oct 2015

Atwood Achiever given contract extension

Atwood Oceanics, Inc. (“Atwood”) has announced that, effective today, one of its subsidiaries agreed to a one-year extension and rate adjustment to its existing contract with Kosmos Energy Ventures (“Kosmos”) for the ultra-deepwater rig, the Atwood Achiever. The Atwood Achiever commenced its three-year drilling services contract with Kosmos in November, 2014, for operations offshore Northwest Africa. The agreement adjusts the operating .... [+ read more] day rate to approximately USD495,500, net of taxes, and extends the contract end date to November, 2018. As part of the agreement, Kosmos has an option, which may be exercised at any time through October 1st, 2016, to revert the contract to the original operating day rate and original end date. Exercising this option will result in a payment that includes the difference in day rates, taxes, and an administrative fee covering the time periods for which the reduced day rate was invoiced.

30 Sep 2015

Lundin completes drilling of Alta appraisal wells

Lundin Norway AS, operator of production licence 609, has completed the drilling of appraisal wells 7220/11-3 and 7220/11-3 A on the oil and gas discovery 7220/11-1 (Alta). The wells were drilled about four kilometres south of discovery well 7220/11-1 and approximately three kilometres northeast of appraisal wells 7220/11-2 and 7220/11-2 A. Discovery 7220/11-1 was proven in chalk rocks in the .... [+ read more] Gipsdalen group in October 2014. After drilling of the discovery well, the operator's resource estimate for the discovery was between 14 and 50 million Sm3 recoverable oil and between 5 and 17 billion Sm3 recoverable gas. The purpose of the wells was to delineate discovery 7220/11-1, and additionally to investigate the extent of the reservoir and hydrocarbon columns. Well 7220/11-3 encountered a 75-metre thick gas column and the upper part of an oil column in chalk rocks in the Gipsdalen group of good to very good reservoir quality. Due to technical challenges, the well was plugged. A decision was made to drill a sidetrack, 7220/11-3 A, about 400 metres to the southeast. The well encountered a 74-metre hydrocarbon column, 30 metres of which was a gas column and 44 metres was an oil column in reservoir rocks of good to poor reservoir quality. The age of the reservoir rock is uncertain, but is assumed to be of Triassic and/or Permian age. The well was temporarily plugged and abandoned to have the opportunity to return to it to drill deeper and, if relevant, perform a production test. Pressure gradients from wells 7220/11-3 and 7220/11-3 A show communication with discovery well 7220/11-1. Extensive data acquisition and sampling have been carried out in both wells. The results from the appraisal wells are important for the further work of mapping the east flank of the discovery. The resource estimate will be reassessed based on the new data. These are the fourth and fifth exploration wells in production licence 609. The licence was awarded in the 21st licensing round in 2011. Appraisal wells 7220/11-3 and 7220/11-3 A were drilled to measured depths of 1926 metres and 2105 metres, respectively, and vertical depths of 1925 and 1962 metres below sea level, respectively, and were terminated in the Gipsdalen group of Permian age. The water depth is 397 metres. The wells were drilled by the Island Innovator drilling facility, which will now drill wildcat well 7220/6-2 in the same production licence.

30 Sep 2015

Borgsten Dolphin - Early termination

Dolphin Drilling Ltd, a subsidiary of Fred. Olsen Energy ASA, has entered into an early termination agreement with Total E&P UK for the tender support vessel Borgsten Dolphin which will result in a cessation of offshore services on 1st October 2016 and the unit mobilising inshore for expected cold stacking thereafter. Total will pay an early termination fee of approximately $22.1 .... [+ read more] million in addition to payment for services provided until 1st October 2016.

28 Sep 2015

Shell suspends Alaskan exploration plan

Shell today provided an update on the Burger J exploration well, located in Alaska’s Chukchi Sea. The Burger J well is approximately 150 miles from Barrow, Alaska, in about 150 feet of water. Shell safely drilled the well to a total depth of 6,800 feet this summer in a basin that demonstrates many of the key attributes of a major petroleum .... [+ read more] basin. For an area equivalent to half the size of the Gulf of Mexico, this basin remains substantially under-explored. Shell has found indications of oil and gas in the Burger J well, but these are not sufficient to warrant further exploration in the Burger prospect. The well will be sealed and abandoned in accordance with U.S. regulations. Shell will now cease further exploration activity in offshore Alaska for the foreseeable future. This decision reflects both the Burger J well result, the high costs associated with the project, and the challenging and unpredictable federal regulatory environment in offshore Alaska. Whether the cessation of drilling activities means that both the Polar Pioneer and Noble Discoverer rigs will be released from their current contracts is not yet clear.

28 Sep 2015

Freeport-McMoran strikes at Horn Mountain Deep well in US GoM

Freeport-McMoRan Inc. has announced positive drilling results from the Freeport-McMoRan Oil & Gas (“FM O&G”) 100% owned Horn Mountain Deep well in the US GoM. Initial production from this well, which will be tied back to existing facilities, is expected in first half 2017. This well, combined with two follow on development wells at Horn Mountain Deep, may be capable of .... [+ read more] producing an aggregate of 30,000 barrels of oil equivalents per day (BOE/d). During September 2015, the Horn Mountain Deep well was drilled to a total depth of approximately 16,925 feet. Logging while drilling logs indicated that the well encountered a total of approximately 142 net feet of Middle Miocene oil pay with excellent reservoir characteristics. In addition, these results indicate the presence of sand sections deeper than known pay sections in the field. The 100% owned Horn Mountain production facilities in FM O&G’s Mississippi Canyon area are capable of processing 75 MBbls of oil per day. Since commencing development activities in 2014 at its three 100% owned production platforms in the Deepwater GoM, FM O&G has drilled 12 wells, all with positive results. Three of these wells have been brought on production, and FM O&G plans to complete and place the remaining additional wells on production in late 2015, 2016 and 2017.

25 Sep 2015

North Falkland Basin Exploration Update

Rockhopper Exploration plc (AIM: RKH), the oil and gas exploration and production company with interests in the North Falkland Basin and the Greater Mediterranean region, is pleased to announce that agreement has been reached to drill a further well on the Isobel/Elaine complex. The re-drill well will target the Isobel Deep reservoir which was oil bearing in well 14/20-1, .... [+ read more] but could not be logged or sampled for mechanical reasons. This new well will be drilled a suitable distance (approximately 4km) from the original well bore and is also expected to encounter additional reservoir targets in the Elaine South and Isobel Shallow Fans. This well will replace the Jayne East well in the current drilling campaign (subject to the final regulatory approvals). As part of the agreement to drill a further well on the Isobel/Elaine complex, Rockhopper has reached agreement with Falkland Oil & Gas Limited ("FOGL") on the terms of compensation for not drilling the Jayne East well. Under the agreement, Rockhopper will pay FOGL $4.0 million ($2.0 million immediately with the balance expected to be paid later in 2016). As per the original farm out agreement, Rockhopper and Premier Oil will carry FOGL on its 40% equity share of the re-drill well costs. The rig, which is currently drilling to the south of the Falkland Islands, is expected to return to the North Falkland Basin in mid to late October 2015.

25 Sep 2015

Noble completes Cheetah exploration well in Cameroon

Noble Energy, Inc. (“Noble”) has announced that the Cheetah exploration well in the Tilapia license offshore Cameroon reached the targeted Cretaceous interval and is being plugged and abandoned. The well encountered both crude oil and natural gas shows in multiple non-commercial reservoir sands. Results from the well are being integrated into Noble’s geologic modeling for the remaining prospectivity in the .... [+ read more] Tilapia license. The rig, which drilled the Cheetah well to a total depth of approximately 13,320 feet, will be released at the completion of well operations.

23 Sep 2015

Primelione spuds LS23-1-1 well in China

Primeline Energy Holdings Inc. (“Primeline”) has announced that the drilling of the LS23-1-1 exploration well has commenced to tap into resources near its LS36-1 gas field production facility. As recently announced, Primeline’s drilling contractor China Oilfield Services Ltd (“COSL”) started to tow the drilling rig, HYSY941, on September 15th 2015. The rig arrived at LS23-1-1 on September 17th 2015 and the .... [+ read more] subsequent jackup and loading operation was successfully completed. LS23-1-1 was spudded on September 23rd, 2015. The LS23-1-1 well is in 81 m of water in Block 33/07 in the East China Sea and is 24 km from the LS36-1 gas field platform. The planned total depth of the well is designed to be 2,688 m with several target zones in Palaeocene sediments. The drilling is scheduled to take approximately 30 days including logging. If hydrocarbons are discovered, additional logging or drill stem tests will be carried out.

23 Sep 2015

Maersk Oil contracts 'Maersk Resilient' jackup for Denmark drilling

Maersk Drilling has been awarded a new contract for the jackup rig Maersk Resilient with Danish oil company Maersk Oil. The firm contract is for three years with an estimated contract value of USD110m. Commencement is expected in October 2015, and Maersk Resilient will do work at various fields in the Danish sector of the North Sea. “We are very pleased .... [+ read more] with this new contract for Maersk Resilient with Maersk Oil, a key customer in the North Sea,” says Claus V. Hemmingsen, CEO in Maersk Drilling and member of the Executive Board in the Maersk Group. Maersk Resilient has since May 2015 been stacked at Invergordon in Scotland, where the rig has undergone various maintenance works. “Maersk Drilling has to continue its excellent performance and continue to build our already strong backlog in order to navigate the low visibility in the market. Therefore, it is also very rewarding that a rig that has been stacked since May 2015 can now return to where she belongs and bring value to our client, Maersk Oil,” says Claus V. Hemmingsen.

23 Sep 2015

Primeline Spuds LS23-1-1 Well

Primeline Energy Holdings Inc. (“Primeline” or the “Company”) (TSXV: PEH) today announced the drilling of its LS23-1-1 exploration well has commenced to tap into resources near its LS36-1 gas field production facility. As recently announced, Primeline’s drilling contractor China Oilfield Services Ltd started to tow the drilling rig, HYSY941, on September 15. The rig arrived at LS23-1-1 on September 17 .... [+ read more] and the subsequent jackup and loading operation was successfully completed. LS23-1-1 was spudded on September 23, 2015. The LS23-1-1 well is in 81 m of water in Block 33/07 in the East China Sea and is 24 km from the LS36-1 gas field platform. The planned total depth of the well is designed to be 2,688 m with several target zones in Palaeocene sediments. The drilling is scheduled to take approximately 30 days including logging. If hydrocarbons are discovered, additional logging or drill stem tests will be carried out. LS23-1-1 is the first exploration well (of two) in Primeline’s current campaign as part of the rolling development program. Based on the result of this well, Primeline will finalize the drilling location of the second well in Block 33/07, which will be either LS30-3-1 or LS23-2-1. Any resources discovered in this drilling campaign can use or share the LS36-1 gas field production infrastructure to speed up development and optimize future development costs and economics.

23 Sep 2015

Blink exploration well commences drilling in the Norwegian Sea

Faroe Petroleum, the independent oil and gas company focusing principally on exploration, appraisal and production opportunities in Norway and the UK, is pleased to announce the commencement of the second Pil/Bue follow-up well with the spudding of exploration well 6406/12-5 S (Faroe 25%) on the Blink prospect. The Blink prospect is located in the Norwegian Sea in Licence PL586, which .... [+ read more] also contains the significant Pil and Bue discoveries (announced in 2014). The licence is located in proximity to the producing Njord field (Faroe 7.5%). The drilling programme will target the Upper Jurassic reservoirs analogous to the Pil, Bue and Draugen field reservoirs. This well follows on directly from the Boomerang well which encountered a 26 metre gross Upper Jurassic intra-Spekk/Rogn sandstone containing estimated recoverable resources of between 13 and 31 million barrels of oil equivalent. The Blink exploration well, located in water depth of approximately 360 metres, is operated by VNG Norge AS (30%) using the Transocean Arctic semi-submersible drilling rig with partners Spike Exploration AS (30%) and Pure E&P Norway AS (15%) and the results will be announced when drilling operations are complete.

22 Sep 2015

Contract associated with cancelled 'West Mira' semisub also now cancelled

Seadrill Limited ("Seadrill"), has been notified by Husky Oil Operations Limited ("Husky") of the cancellation of the drilling contract for the West Mira ("The Unit"). In the fourth quarter of 2012 Seadrill was awarded a five-year contract for the West Mira with Husky for operations in Canada and Greenland. The total estimated base revenue potential was approximately USD1 billion. As stated .... [+ read more] in Seadrill’s second quarter earnings report, due to the late delivery of the Unit, Seadrill tentatively agreed with Husky to reduce the dayrate on the West Mira. The construction contract was subsequently cancelled by Seadrill due to the Shipyard's inability to deliver the Unit within the timeframe required under the contract. Seadrill remains in discussions with Husky to find an alternative solution to meet its drilling requirements.

18 Sep 2015

Suncor targets drilling at Havfrue (Mermaid) prospect

The Norwegian Petroleum Directorate (NPD) has granted Suncor Energy Norge AS a drilling permit for well 25/10-14 S, cf. Section 8 of the Resource Management Regulations. Well 25/10-14 S will be drilled from the Borgland Dolphin drilling facility in position 59°10’01.22’’ north 02°14’43.44’’ east in the central North Sea. The drilling program for well 25/10-14 S concerns the drilling of .... [+ read more] a wildcat well in production licence 571. Suncor Energy Norge AS is the operator with an ownership interest of 60 per cent. The other licensee is Statoil Petroleum AS with 40 per cent. The area in this licence consists of parts of blocks 25/7 and 25/10. Production licence 571 was awarded on 4 February 2011 (APA 2010). This is the second exploration well to be drilled in the licence, but exploration wells have previously been drilled within the area covered by this licence. The permit is contingent upon the operator having secured all other permits and consents required by other authorities before the drilling starts.

17 Sep 2015

VNG makes minor oil discovery in PL 586

VNG Norge AS, operator of production licence 586, is in the process of completing the drilling of wildcat wells 6406/12-4 S and 6406/12-4 A. Well 6406/12-4 S was drilled approx. 33 kilometres southwest of the Njord field in the southern part of the Norwegian Sea and approx. 1.7 kilometres southeast of discovery well 6406/12-3 S (Pil). The primary exploration target .... [+ read more] of well 6406/12-4 S was to prove petroleum in Upper Jurassic sandstones in a southwestern segment, which is adjacent to the 6406/12-3 S discovery (Pil). The well encountered an approx. 590 metre thick unit of Upper Jurassic rocks, 20 metres of which of are sandstone (the Rogn formation) with good reservoir quality. Preliminary estimates of the size of the discovery range between two and five million standard cubic metres (Sm3) of recoverable oil equivalents. The licensees will consider the discovery in conjunction with other nearby discoveries as regards a possible future development. The secondary exploration target was to prove petroleum in Upper Jurassic rocks (sandstone in the Intra Melke formation), the extent, thickness and properties of the reservoir rocks, as well as depth to hydrocarbon contacts. The well encountered 368 metres of sandstone in the Intra Melke formation of varying quality and with traces of oil. The objective of well 6406/12-4 A was to prove petroleum in Upper Jurassic reservoir rocks (sandstone in the Intra Spekk and Intra Melke formations) in a southern segment adjacent to the 6406/12-3 S discovery (Pil). Well 6406/12-4 A encountered about 20 metres of Intra Spekk sandstone and 515 metres of reservoir rocks in the Intra Melke formation, both with poor reservoir properties. The reservoir contains only traces of hydrocarbons. The well was classified as dry. Extensive data acquisition and sampling have been carried out. These are the fourth and fifth wells to be drilled in production licence 586, which was awarded in APA 2010. 6406/12-4 S was drilled to measured and vertical depths of 4318 and 3832 metres below sea level respectively, and was terminated in the Melke formation in the Upper Jurassic. 6406/12-4 A was drilled to measured and vertical depths of 4058 and 3799 metres below sea level respectively, and was terminated in the Melke formation in the Jurassic. Water depth at the site is 319 metres. The wells will now be permanently plugged and abandoned. Wells 6406/12-4 S and A were drilled by the drilling facility Transocean Arctic which now will drill 6406/12-5 S in a northern segment adjacent to the discovery 6406/12-3 S (Pil).

16 Sep 2015

Primeline mobilises jackup rig for drilling of LS23-1-1 well in China

Primeline Energy Holdings Inc. (“Primeline”) today announced that its drilling contractor China Oilfield Service Ltd. (“COSL”) has started the mobilisation of the rig for the drilling operation of LS23-1-1 well. Following the signing of the drilling contract by Primeline with COSL as announced on August 17th, 2015, COSL has completed the site survey of the well locations and other preparations for .... [+ read more] the drilling operations, including the applications for the required operation permits. Primeline held a pre-spud meeting with COSL and all main subcontractors on September 14th. COSL started to tow drilling rig HYSY941 toward the well LS23-1-1 location on the evening of September 15th. The towing operation is expected to last three to five days, subject to weather and sea conditions, followed by jack up, with drilling operations expected to commence around September 22nd.

15 Sep 2015

Seadrill terminates under construction 'West Mira' semisub

Seadrill Limited ("Seadrill" ), has notified Hyundai Heavy Industries Co Ltd. ("HHI") that it has exercised its right to cancel the contract for the construction of the West Mira, a sixth generation ultra-deepwater harsh environment semisubmersible drilling unit ("West Mira"). The West Mira was ordered during the second quarter of 2012 and the delivery date stated in the construction contract was .... [+ read more] by December 31st, 2014. Due to HHI’s inability to deliver the West Mira within the timeframe required under the contract, Seadrill has exercised its cancellation rights. Under the contract terms, Seadrill has the ability to recoup the USD168 million in pre-delivery instalments to HHI, plus accrued interest. In the fourth quarter of 2012 Seadrill was awarded a five year contract for the West Mira with Husky Oil Operations Limited ("Husky") for operations in Canada and Greenland. As stated in Seadrill’s second quarter earnings report, due to the late delivery of the West Mira, Seadrill had tentatively agreed with Husky to reduce the dayrate of the drilling contract. Seadrill remains in discussions with Husky to find an alternative solution to meet its drilling requirements.

14 Sep 2015

'Noble Tom Prosser' enroute to Australia for drilling contract

Carnarvon Petroleum Limited (“Carnarvon”) has provided the following update regarding the upcoming drilling of the Roc-1 well in WA-437-P. Quadrant Energy, the operator of WA-437-P contracted the Noble Tom Prosser (“Tom Prosser”) jackup drilling rig to drill the Roc-1 well and on the 11th September 2015, the Tom Prosser began its voyage from Singapore on route to Australia and is expected .... [+ read more] to arrive in Dampier between 19th and 21st September 2015. The rig will drill a well for Vermillion Energy at the Wandoo oil field before commencing Roc-1 drilling operations. At this time, the best estimate for the commencement of the Roc-1 well is early to mid-November 2015 and the well is estimated to take around 50 to 60 days to complete

14 Sep 2015

Shell comes up dry in Norway at PL 793

A/S Norske Shell, operator of production licence 793, is in the process of completing the drilling of wildcat well 6407/10-5. The well has been drilled about 20 kilometres southwest of the Draugen field, less than 10 kilometres southeast of the Njord field in the southern section of the Norwegian Sea and about 100 kilometres north of Kristiansund. The purpose of .... [+ read more] the well was to prove petroleum in reservoir rock from the Upper Jurassic (the Rogn Formation). The well was drilled 330 metres into the Rogn Formation, of which 134 metres were sandstone of moderate to good reservoir quality. The well is dry. Data acquistion has been carried out from the well. This is the first exploration well in production licence 793 awarded in APA 2015. The well was drilled to a vertical depth of 2850 metres below the sea surface and terminated in the Rogn Formation in Upper Jurassic. The water depth at the site is 336 metres. The well will now be permanently plugged and abandoned. The well was drilled by the drilling facility Transocean Barents.

9 Sep 2015

Lundin gets go ahead for new wildcat well

The Norwegian Petroleum Directorate has granted Lundin Norway AS a drilling permit for well 16/1-25 S, cf. Section 8 of the Resource Management Regulations. Well 16/1-25 S will be drilled from the Bredford Dolphin drilling facility in position 58°46’57.096” north 02°15’17.386”east. The drilling program for well 16/1-25 S concerns the drilling of a wildcat well in production licence 338 .... [+ read more] C. Lundin is the operator with an ownership interest of 80 per cent. The other licensee is OMV (Norway) AS with 20 per cent. The area in this licence consists of part of block 16/1. The well is being drilled south of the Edvard Grieg field in the central part of the North Sea. Production licence 338 C was separated from production licence 338 and awarded on 16 December 2014. This is the second exploration well to be drilled within the area covered by the permit. The permit is contingent upon the operator having secured all other permits and consents required by other authorities before the drilling starts.

7 Sep 2015

Odfjell Drilling announces new contract award from Wintershall Norge AS

Wintershall Norge AS has awarded Odfjell Drilling's semi-submersible Deepsea Stavanger a contract for the drilling of production wells on the Maria field in the Haltenbanken area on the Norwegian Continental Shelf. The firm contract is for six wells with an expected duration of 574 days and an estimated contract value of USD175 million. Contract commencement is estimated to 1 April 2017. .... [+ read more] The contract additionally contains a one-well option prior to the firm contract and two wells after the firm period. The estimated contract value of the optional wells is USD 98 million. Deepsea Stavanger is currently employed by BP in Angola on a contract that is expected to mature during November this year. Odfjell Drilling continues to market the rig in order to secure temporary employment for Deepsea Stavanger to fill the gap to its start-up on the Maria field.

4 Sep 2015

Rosneft contracts 'Hakuryu-5' for Vietnam drilling

Rosneft Vietnam B.V., a company of Rosneft Group, and Japan Drilling Co., Ltd. (“JDC”) represented by its subsidiary Hakuryu 5, Inc. signed an agreement on provision and operation of the marine drilling rig Hakuryu-5, for the purposes of drilling exploration wells within the framework of Rosneft’s projects in Vietnam. It is planned to drill two wells in Blocks 06.1 and 05-3/11 .... [+ read more] in the Nam Con Son basin offshore Vietnam in 2016. Consistent implementation of drilling works at both blocks will ensure synergy between the two projects and help reduce the timelines for implementation of the works, thus maximizing the efficiency of exploration activities at the Company’s Vietnamese assets. Commenting on the document’s signing, Rosneft Chairman of the Management Board Igor Sechin noted: “We have always welcomed participation of high technology partners from Japan in implementation of the Company’s projects. Despite the difficult macroeconomic situation, today we are expanding our cooperation in the area of exploration and production of hydrocarbons by executing contracts not only in Russia, but also in Asia Pacific.”

4 Sep 2015

COSCO announces ruling on the 'Dalian Developer' case

The Board of Directors (“Board”) of COSCO Corporation (Singapore) Limited ( “COSCO”) refers to the announcement on 17th October 2013 in relation to the DP3 Deepwater Drillship construction contract (the “Contract”) between COSCO (Dalian) Shipyard Co., Ltd (“COSCO Dalian”) (a subsidiary of the Company’s 51% owned subsidiary, COSCO Shipyard Group Co., Ltd) and Dalian Deepwater Developer Ltd (the “Shipowner”). The .... [+ read more] Shipowner had served a notice of termination and submitted a request for arbitration in London. The Board wishes to announce that an arbitration award has now been issued. The arbitral tribunal has ruled that COSCO Dalian, having repaid to the Shipowner the first instalment together with interest thereon is not liable to the Shipowner for any further liabilities. COSCO will make announcements of any material development in relation to the DP3 Deepwater Drillship at the appropriate junctures.

4 Sep 2015

Statoil concludes drilling at PL 104

Statoil Petroleum AS, operator of production licence 104, has concluded the drilling of wildcat well 30/9-27 S. The well was drilled around 7 kilometres west of the Oseberg Sør-field in the northern part of the North Sea, 150 kilometres west of Bergen. The purpose of the well was to prove petroleum in Middle Jurassic reservoir rocks (the Tarbert Formation). The .... [+ read more] well encountered a 34-metre oil column in sandstone with moderate to good reservoir quality. The oil/water contact was encountered 3,242 metres below sea level. Preliminary estimates of the size of the discovery range between one and two million standard cubic metres (Sm3) of recoverable oil equivalents. The discovery will be developed together with the Oseberg Delta 2 project, which is under development, and the licensees are assessing a production well in the structure encountered by wildcat well 30/9-27 S. Data acquisition has been carried out. This is the 26th exploration well drilled in production licence 104. The licence was awarded in the ninth licensing round. The well was drilled to a measured and vertical depth of 3,989 and 3,353 metres, respectively, below the sea surface and was terminated in Middle Jurassic rocks (the Ness Formation). The water depth at the site is 103 metres. The well has been permanently plugged and abandoned. Well 30/9-27 S was drilled by the drilling facility Songa Delta, which will now drill development well 30/9-O-2 H in production licence 104, where Statoil Petroleum AS is the operator.

3 Sep 2015

Premier comes up dry at Myrhauk prospect

Premier Oil Norge AS, operator of production licence 539, is in the process of completing the drilling of wildcat well 3/7-10 S. The well has been drilled about 45 kilometres northeast of the Valhall field in the southern section of the North Sea and 300 kilometres southwest of Stavanger. The purpose with the well was to prove petroleum in the .... [+ read more] Upper and Middle Jurassic reservoir rocks (the Ula and Bryne formations). The well did not encounter the Ula formation. The Bryne formation was encountered with a thickness of about 110 metres, of which 45 metres with moderate reservoir quality. The well is dry. Data acquisition and sampling were carried out. The well is the first exploration well in production licence 539, awarded in APA 2009. Well 3/7-10 S was drilled to a measured and vertical depth of 3511 and 3464 metres below sea level, respectively, and was terminated in the Skagerrak formation in the Upper Triassic. The water depth at the site is 68.5 metres. The well will now be permanently plugged and abandoned. The well was drilled by the drilling facility Mærsk Guardian, which now will proceed to Fredrikshavn to be laid up.

2 Sep 2015

UMW takes delivery of newbuild 'UMW Naga 8' jackup

UMW Oil & Gas Corporation Berhad (UMW-OG) officially took delivery of its latest jack-up rig; UMW NAGA 8 from Keppel FELS Limited (Keppel FELS), a subsidiary of Keppel Offshore & Marine Ltd (Keppel O&M). Designed to address higher requirement market, UMW NAGA 8 is the third KFELS B Class jack-up rig in UMW-OG’s fleet; the first two being UMW NAGA .... [+ read more] 4 and UMW NAGA 5, which were delivered in 2013 and 2014, respectively. Similar to both its predecessors, UMW NAGA 8 is a premium jack-up drilling rig capable of operating in water depths of up to 400 feet (approximately 125 metres) and drilling to a total depth of 30,000 feet (approximately 9,144 metres) sub-sea. Equipped with the newest and most technologically advanced equipment, additional features include an advanced and fully-automated high capacity rack and pinion elevating system, self-positioning fixation system and facilities capable of accommodating 150 personnels. Present to receive the rig at Keppel FELS’s yard was Rohaizad Darus, President, UMW-OG, who shared, “At 400 feet water depth, this latest rig will enable us to address a niche market where there is lesser competition. The additional asset will also provide us with the capacity to cover a wider market, both regionally and globally to continue our growth once the market recovers.” UMW NAGA 8 is currently being prepared to be mobilised for a potential client in Southeast Asia.

2 Sep 2015

Petrobras cancels 'Titanium Explorer' drillship contract

Vantage Drilling Company (2Vantage") received a notice dated August 31st, 2015 (the "Notice") from Petrobras America, Inc. ("PAI") and Petrobras Venezuela Investments & Services B.V. ("PVIS") stating that PAI and PVIS were terminating the Agreement for the Provision of Services Contract for the Titanium Explorer dated February 4th, 2009 (the "Drilling Contract"), between PVIS and Vantage Deepwater Drilling Company, a wholly-owned .... [+ read more] indirect subsidiary of Vantage, and which had been novated to PAI. The Notice alleges that Vantage has breached its obligations under the Drilling Contract. The Notice does not provide any explanation as to the facts and conduct that constitute a breach by Vantage of its obligations under the Drilling Contract. Vantage strongly disagrees with the allegations of contractual breaches made by PAI and PVIS in the Notice. Vantage has filed for arbitration to challenge the assertions made in the Notice and to assert that the Notice is a wrongful attempt to terminate the Drilling Contract. Vantage believes that it is in compliance with all of its obligations under the Drilling Contract.

2 Sep 2015

COSL semisub hired to drill in Okhotsk Sea

Magadanmorneftegaz, Lisyanskmorneftegaz (joint ventures of Rosneft and Statoil) and China Oilfield Services Limited (“COSL”) have signed a contract to drill two exploration wells in 2016. The wells will be drilled in the Magadan-1 and Lisyansky areas of the Okhotsk Sea. COSL offered its semi-submersible drilling rig Nanhai-9 and won the tender based on a combined score of technical and economic parameters. .... [+ read more] The rig was positively evaluated by an audit for compliance with Russian and international requirements. Commenting on the signed document, Igor Sechin, Rosneft Chairman of the Management Board, said: "The agreements reached opens up new prospects for further cooperation between leaders of the oil and gas industry in Russia, Norway and China in the exploration of oil and gas resources."

1 Sep 2015

Sea Lion-1 well spud date pushed back to mid-September

3D Oil Limited (“3D”) a member of the VIC/P57 joint venture being operated by Carnarvon Hibiscus Pty Ltd. (“CHPL”) has advised that the Sea Lion-1 exploration well is now not expected to spud until approximately mid-September 2015, due to delays with the rig handover. CHPL contracted the West Telesto jackup for drilling operations, however, delivery of the unit is being held .... [+ read more] up due to adverse weather conditions and thus preventing it being released by Origin Energy who are using the jackup to drill on the Yolla field.

31 Aug 2015

Pemex terminates 'Deep Driller 7' contract

Pemex has terminated a contract for the Aban Offshore jackup Deep Driller 7 about four months early, exercising an early termination clause. The unit which is owned by Deep Drilling Invest Pte. Ltd. (“DDI”) was released from its contract with the Mexican operator on the 27th August 2015 according to a statement released on the Oslo Bors. .... [+ read more]

31 Aug 2015

Statoil comes up dry at Knappen prospect

Statoil Petroleum AS, operator of production licence 72 B, is in the process of completing the drilling of wildcat well 16/7-11 on behalf of production licences 72 B, 72 D and 72 E. The well was drilled approximately 10 kilometres east of the Sleipner A platform in the central part of the North Sea and 220 kilometres west of Stavanger. .... [+ read more] The purpose of the well was to prove petroleum in Upper Trias reservoir rocks (the Skagerrak formation). The well was drilled 97 metres into the Skagerrak formation, about 50 metres of which was in thin sandstone layers with moderate to good reservoir quality. The well is dry. Data acquisition has been carried out. This is the second exploration well in production licence 72 B. Well 16/7-11 was drilled to a vertical depth of 2,625 metres below sea level and was terminated in the Skagerrak formation. The water depth at the site is 81 metres. The well will now be permanently plugged and abandoned. The well was drilled by the drilling facility Songa Trym, which will now drill wildcat well 25/11-28 in the central part of the North Sea in production licence 169, where Statoil is the operator.

27 Aug 2015

Statoil set to spud wildcat in PL 169

The Norwegian Petroleum Directorate has granted Statoil Petroleum AS a drilling permit for well 25/11-28, cf. Section 8 of the Resource Management Regulations. Well 25/11-28 will be drilled from the drilling facility Songa Trym in position 59°00’31.1’’ north 02°21’59.3’’ east. The drilling program for well 25/11-28 concerns the drilling of a wildcat well in production licence 169. Statoil is the .... [+ read more] operator with an ownership interest of 57 per cent. The other licensees are Petoro AS with 30 per cent and ExxonMobil & Production Norway AS with 13 per cent. The area in this licence consists of parts of the blocks 25/8, and 25/11. The well is being drilled south of the Grane field in the central part of the North Sea. Production licence 169 awarded on 1 March 1991 (13th licensing round). This is the 15th wildcat well to be drilled in the license. The permit is contingent upon the operator having secured all other permits and consents required by other authorities before the drilling starts.

26 Aug 2015

Oro Negro reaches rate reduction deal with Pemex for four jackups

Integradora de Servicios Petroleros Oro Negro, S.A.P.O. de C.V. (“Oro Negro”) and Pemex-Exploración y Producción (“Pemex”) have agreed on terms for amending their outstanding charter leases for Oro Negro’s Primus, Laurus, Fortius, and Decus jackup rigs. The amendments provide that the daily rental rate payable to Oro Negro for each of the rigs will be reduced from approximately USD160,000 to USD .... [+ read more] 130,000, for the period June 1st, 2015 through May 31st, 2016. From and after June 1st, 2016, the daily rental rate will return to approximately USD160,000. In addition, the charter leases will each be extended by one year.

26 Aug 2015

Shell set for drilling at Portrush prospect

The Norwegian Petroleum Directorate has granted A/S Norske Shell a drilling permit for well 6407/10-5 S, cf. Section 8 of the Resource Management Regulations. Well 6407/10-5 will be drilled from the Transocean Barents drilling facility in position 64°12’41.7” north and 7°16’34.25” east. The drilling programme for well 6407/10-5 relates to the drilling of a wildcat well in production licence 793. .... [+ read more] A/S Norske Shell is the operator with an ownership interest of 40 per cent. The other licensees are Petoro AS (20 per cent), VNG Norge AS (20 per cent) and Faroe Petroleum Norge AS (20 per cent). The area in this licence consists of parts of the blocks 6407/7, 8, 10, 11. The well is drilled about five kilometres southeast of the Njord field and about 25 kilometres southwest of Draugen. Production licence 793 was awarded on 6 February 2015 in APA 2014 on the Norwegian shelf. This is the first well to be drilled in the licence. The permit is contingent upon the operator having secured all other permits and consents required by other authorities before the drilling starts.

25 Aug 2015

Lundin confirms strike at Edvard Greig appraisal

Lundin Norway AS, operator of production licence 338, is in the process of completing the drilling of appraisal well 16/1-23 S on the Edvard Grieg oil field in the central section of the North Sea. Appraisal well 16/1-23 S is drilled 2.4 kilometres southeast of the Edvard Grieg platform. The field was proven in the autumn of 2007 and .... [+ read more] consists of Cretaceous, Jurassic and Triassic reservoir rocks. Prior to well 16/1-23 S being drilled, the operator's resource estimate for the field was 29.8 million standard cubic metres of recoverable oil. The purpose of the well was to investigate reservoir rocks, reservoir properties and the oil/water contact as regards delineating the south-eastern section of the Edvard Grieg field. In addition, the purpose was to optimise the drainage strategy for the best possible location of production wells in this area. The well 16/1-23 S encountered a total oil column of 67 metres in conglomorate sandstone with moderate to good reservoir quality. The oil/water contact was encountered 1933.5m below the sea surface, which is 5.5 metres shallower than the contact in the rest of the field. Extensive data acquisition and sampling have been carried out. A total of five small-scale formation tests (mini DSTs) have been carried out in the oil and water zone, with test production of one-metre intervals through the drilling string. The tests in the oil zone showed good flow properties, whereas the flow rate was moderate in the water zone. Preliminary calculations show that the results from the well may result in an increase of between 1 and 8 million standard cubic metres recoverable oil in this section of the Edvard Grieg field. Further work is expected to reduce the uncertainty of this estimate. This is the tenth exploration well in production licence 338 and the seventh exploration well on the Edvard Grieg field. The licence was awarded in APA 2004. A Plan for Development and Operation (PDO) for the Edvard Grieg field was submitted to the Ministry of Petroleum and Energy on 16 January 2012. Appraisal well 16/1-23 S is drilled to a measured and vertical depth of 2130 and 2043 metres respectively below the sea surface and terminated in granite bedrock. The well will be permanently plugged and abandoned. Water depth at the site is 108 metres. The well was drilled by the drilling facility Rowan Viking, which now will continue to drill production and injection wells on the Edvard Grieg field.

24 Aug 2015

'Songa Endurance' semisub is delivered by DSME

Songa Offshore SE (“Songa”) has today taken delivery of the Songa Endurance semisub from Daewoo Shipbuilding & Marine Engineering (“DSME”) in South Korea. Songa Endurance will shortly depart South Korea enroute to Norway for commencement of an eight-year drilling contract with Statoil, with first assignment on the Troll Field on the Norwegian continental shelf. The voyage to Norway will take place .... [+ read more] with tow-assist and the rig will arrive with all third party equipment installed and ready for final acceptance testing. Commencement of drilling operations is expected to take place around year-end. Songa Endurance is a sixth generation, high specification, harsh environment, midwater rig designed for efficient year around drilling, completion, testing and intervention operations in water depths up to 500 meters. The rig is certified DP3 and is equipped with a "state-of-the-art" drill-floor and an efficient layout with improved safety and working environment features. Songa Endurance is the second rig in a series of four Category D rigs specifically built for and contracted to Statoil.

21 Aug 2015

PSA approves exploration drilling in PL700b

Lundin Norway AS (“Lundin”) is the operator for production licence 700B and has received consent to drill exploration well 6407/10-4 in the Norwegian Sea. Drilling will begin in September 2015 at the earliest and estimated to last 69 days, depending on whether a discovery is made. .... [+ read more]

21 Aug 2015

Lundin receives approval to drill at Rolvsnes prospect

Lundin Norway AS (“Lundin”) has received consent for drilling of exploration well 16/1-25S in the North Sea. Lundin is the operator for production licence 338C in block 16/1 in the central North Sea. Exploration well 16/1-25S is to be drilled in a prospect called Rolvsnes. Drilling will begin in mid-September 2015 at the earliest and is estimated to last 45 days, .... [+ read more] depending on whether a discovery is made.

19 Aug 2015

Wintershall given approval to spud wildcat well in PL248

The Norwegian Petroleum Directorate (NPD) has granted Wintershall Norge AS a drilling permit for well 35/12-5 S, cf. Section 8 of the Resource Management Regulations. Well 35/11-18 will be drilled from the Borgland Dolphin drilling facility in position 61°09`24.40" north and 03°20`38.09" east after concluding the drilling of wildcat well 6507/3-11 S for E.ON E&P NORGE AS in production licence 650. .... [+ read more] The drilling programme for well 35/11-18 relates to the drilling of a wildcat well in production licence 248. Wintershall Norge AS is the operator with an ownership interest of 60 per cent. The other licensee is Petoro AS with 40 per cent. The area in this permit consists of parts of blocks 35/8 and 35/11. The well will be drilled about 100 km south-west of Florø and about 20 km north-west of the Fram field. Production licence 248 was awarded on 4 June 1999 (NST99). This is the second wildcat well to be drilled in the licence. The permit is contingent on the operator securing all other consents and permits required by other authorities prior to commencing the drilling activity.

17 Aug 2015

Primeline Energy to drill two wells utilising 'HAI YANG SHI YOU 941' jackup

Primeline Energy Holdings Inc. (“Primeline”) today announced that it has entered into a turnkey drilling contract with China Oilfield Service Ltd. (“COSL!) for its 2015 exploration programme of two wells in Block 33/07 in the East China Sea. Primeline signed a letter of intent with COSL on 22nd July with regards to the drilling work, and has since negotiated the formal .... [+ read more] drilling contract with COSL which was entered into on 14th August and under which the drilling operations will now proceed. Under the terms of the drilling contract, COSL has agreed to drill two wells for Primeline on a turnkey basis to the depth and target zone specified by Primeline. If hydrocarbons are discovered, COSL will also conduct tests for Primeline either on a turnkey basis or as a day rate operation as selected by Primeline. Primeline has decided to drill LS23-1-1 as the first well and, depending on the results, will then drill either location LS23-2-1 or LS30-3-1 as the second well. Primeline has the option to suspend operations after the first well if it is necessary to spend additional time carrying out any studies necessary before drilling the second well in order to ensure it is drilled in the optimal location. This two well drilling campaign is part of the rolling development programme Primeline and CNOOC are implementing in the southern part of East China Sea following the completion of development of LS36-1 gas field. Now that LS36-1 gas field is in production, thereby establishing a production hub and access to market, Primeline intends to speed up the exploration programme in order to discover more resources in the nearby area to capitalize the infrastructure and access to market. Any additional resources that are discovered in the area nearby LS36-1 in Block 33/07 can share the infrastructure so any future incremental development will be quick and cost effective. According to COSL’s current planning, LS23-1-1 is scheduled to be spudded around the middle of September 2015 using drilling rig HYSY941. An update will be announced when the drilling operations commence.

17 Aug 2015

Otto Energy makes sub-commercial find at Hawkeye-1

Red Emperor Resources NL (“Red Emperor”) has provided the following update with respect to the drilling of the Hawkeye-1 exploration well, offshore Palawan Basin in the Philippines. The Hawkeye-1 exploration well was drilled to the planned total depth of 2,920m with the top reservoir intersected at 2,710m. Hydrocarbons were logged between 2,710m – 2,737m in reservoir of variable quality. .... [+ read more] The upper reservoir section between 2,710m – 2,724m is interpreted to be gas bearing at sub-commercial volumes. The second, poorer quality reservoir (2,724m – 2,737m) provided evidence of fluorescence, usually an indicator of liquid hydrocarbons, from hand cutting returns. Unfortunately, even if confirmed oil bearing, the combination of poor reservoir and low net pay would render the potential oil leg sub-commercial. Below 2,737m water was inferred from log observations in a reservoir sequence of good quality. While the Hawkeye-1 exploration well has proven the existence of hydrocarbons in SC55, the hydrocarbon size discovered appears to be at the low end of expectations and not likely economic to develop. Hawkeye-1 will now be plugged and abandoned with results from the well to be analysed with respect to other prospects, including Cinco, in the license that potentially share the same charge source.

17 Aug 2015

VNG lines up spudding of new exploration well at PL586

The Norwegian Petroleum Directorate (NPD) has issued a drilling permit to VNG Norge AS for well 6406/12-4 A, cf. Section 8 of the Resource Management Regulations. Well 6406/12-4 A will be drilled from the Transocean Arctic drilling facility in position 64°1’7.48” north and 6°46’31.29” east after drilling wildcat well 6406/12-4 S in production licence 586. The drilling programme for well .... [+ read more] 6406/12-4 A relates to the drilling of a wildcat well in production licence 586. VNG Norge AS is the operator with an ownership interest of 30 per cent. The other licensees are Spike Exploration Holding AS (30 per cent), Faroe Petroleum Norge AS (25 per cent) and Rocksource Exploration Norway AS (15 per cent). The area in this permit consists of part of block 6406/11 and part of block 6406/12. The well will be drilled about 33 km south-west of the Njord field. Production licence 586 was awarded on 4 February 2011 (APA 2010). This is the fifth exploration well to be drilled in the licence. The permit is contingent on the operator securing all other permits and consents required by other authorities prior to commencing the drilling activity.

14 Aug 2015

Chloe Marine Corporation Ltd. announces possible sale of 'Deepsea Metro II'

The board of directors of Chloe Marine Corporation Ltd. has formally resolved to initiate a process to sell the ultra-deepwater drillship "Deepsea Metro II" and have appointed Pareto Offshore AS as the exclusive broker for the sale of the vessel. The ultra-deepwater drillship, Deepsea Metro II, is owned by Chloe Marine Corporation Ltd, a company owned by Deep Sea Metro Ltd., .... [+ read more] a joint venture between Metro Exploration (60%) and Odfjell Drilling (40%). Odfjell Drilling is the manager of the vessel. Deepsea Metro II is currently ready stacked in Curacao following completion of its contract with Petrobras in Brazil, which concluded in May 2015.

13 Aug 2015

Midleton exploration well deemed non-commercial

Lansdowne Oil & Gas (“Lansdowne”), the independent oil and gas company focussed on offshore Ireland has announced that drilling at the Midleton exploration well in the Celtic Sea has been completed. Drilling was carried out using the Ocean Guardian semisub by the operator (PSE Kinsale Energy Limited), with the spudding of the well (49/11-3) taking place on 29th July 2015. The .... [+ read more] well has now reached a total depth (TD) of 3,480 feet and whilst good quality reservoirs were encountered, the volumes were not commercial and some were water bearing. The well is now being plugged and abandoned.

13 Aug 2015

Vantage cancels 'Cobalt Explorer' construction

On August 13th, 2015, pursuant to the terms of the contract for the construction and sale of the Cobalt Explorer, Vantage Drilling Company (“Vantage”) announced that it has terminated the contract. Vantage will seek to recover all funds paid to Daewoo Shipbuilding & Marine Engineering (“DSME”) totalling approximately USD59.5 million plus contractual interest and any other amounts due under applicable law. .... [+ read more] DSME may seek to challenge Vantage’s ability to terminate the contract pursuant to arbitration provisions in the contract, which would result in a delay in recovery of any amounts that might be due to us under the contract. In addition, DSME itself may seek to terminate the contract for our failure to make the second milestone payment for the Cobalt Explorer under the contract. Such termination by DSME might entitle it to retain all supplies delivered to the shipyard and all milestone and other payments made by us to the shipyard to date, and to elect to sell the vessel and claim any deficiency in proceeds against us. We may consider future alternatives with DSME for the delivery of the Cobalt Explorer.

12 Aug 2015

E.ON comes up dry at Salander prospect

E.ON E&P Norge AS, operator of production licence 650, has completed drilling wildcat well 6507/3-11 S. The well was drilled about 12 kilometres east of the Skarv field in the Norwegian Sea. The primary and secondary exploration targets for the well were to prove petroleum in Middle and Lower Jurassic reservoir rocks (the Fangst and Båt groups). In the primary .... [+ read more] exploration target, the well encountered approx. 30 metres of reservoir rocks in the Garn formation and 60 metres of reservoir rocks in the Ile formation (the Fangst group), both with very good reservoir quality. In the secondary exploration target, about 95 and 70 metres of reservoir rocks were encountered in the Tilje and Åre formation in the Båt group, respectively, both with good to very good reservoir properties. The well is dry. Data acquisition has been carried out. The well is the first exploration well in production licence 650. The licence was awarded in APA 2011. The well was drilled to measured and vertical depths of 2470 and 2306 metres below the sea surface, respectively, and was terminated in the Åre formation in the Lower Jurassic. Water depth at the site is 350 metres. The well will be permanently plugged and abandoned. Well 6507/3-11 S was drilled by the Borgland Dolphin drilling facility, which will now proceed to production licence 248 in the North Sea to drill wildcat well 35/11-18 where Wintershall Norge AS is the operator.

12 Aug 2015

Lundin strikes oil at Luno II North prospect

Lundin Norge AS, operator of production licence 359, has completed drilling wildcat well 16/4-9 S. The well was drilled about 15 kilometres south of the Edvard Grieg field in the central part of the North Sea and 190 kilometres west of Stavanger. The objective of the well was to prove petroleum in Jurassic to Triassic reservoir rocks. The well encountered .... [+ read more] a 23-metre oil column in conglomeratic sandstone in the mentioned rocks, of which 18 metres were of moderate reservoir quality. The oil/water contact was encountered 1954 metres below the sea surface. The entire reservoir, including the water zone, consists of sandstones and conglomerates with a thickness of about 230 metres. Preliminary estimates place the size of the discovery between two and four million standard cubic metres (Sm3) of recoverable oil equivalents. The discovery will be developed along with the 16/4-6 S discovery, and tie-in to the Edvard Grieg field will be considered. Extensive data acquisition and sampling have been carried out. A formation test was carried out. The production rate was 150 standard cubic metres (Sm3) of oil per flow day through a 32/64-inch nozzle opening. The test showed moderate flow properties. The oil is light with a gas/oil ratio of 210 Sm3/Sm3. This is the fourth exploration well to be drilled in production licence 359. The licence was awarded in APA 2005. The well was drilled to measured and vertical depths of 2358 and 2305 metres below the sea surface, respectively, and was terminated in Triassic rocks. The water depth is 100 metres. The well will be permanently plugged and abandoned. The 16/4-9 S well was drilled by the Bredford Dolphin drilling facility, which will now drill wildcat well 6306/5-2 in production licence 642 in the Norwegian Sea, where Repsol Exploration Norge AS is the operator.

12 Aug 2015

Statoil set to spud new wildcat well in Norway

The Norwegian Petroleum Directorate (NPD) has granted Statoil Petroleum AS a drilling permit for well 16/7-11, cf. Section 8 of the Resource Management Regulations. Well 16/7-11 will be drilled from the Songa Trym drilling facility in position 58°22’52.98’’ north 02°04’05.00’’ east. The drilling programme for well 16/7-11 relates to the drilling of a wildcat well in production licence 072 B. .... [+ read more] Statoil is the operator with a 50 per cent ownership interest. The other licensee is ExxonMobil Exploration & Production Norway AS with 50 per cent. The area in this licence consists of parts of block 16/7. The well will be drilled east of the Sleipner Øst field in the central sector of the North Sea. Production licence 072 B was awarded on 24 September 2001. This is the second exploration well to be drilled in the licence. The permit is contingent on the operator securing all other permits and consents required by other authorities prior to commencing the drilling activity.

11 Aug 2015

Quadrant Energy comes up dry at Levitt-1

Karoon Gas Australia Ltd (“Karoon”) announced that as of 19:30 AWST on 8th August 2015, the Levitt-1 exploration well in WA-482-P Carnarvon Basin, off- shore Western Australia reached a final total depth of 4,929 mRT. No hydrocarbons shows were noted while drilling and petrophysical analysis of LWD data indicates the good quality reservoir of the Legendre and North Rankin .... [+ read more] formations to be water bearing at this location. Since the June 2015 Quarterly Report, announced 31st July 2015, the 9-5/8” casing was run and cemented in place. The 8-1/2” hole section was then drilled 504 metres from 4,425 mRT to TD. A wireline logging program is now underway. Once the wireline logging program is complete, the well will be plugged and abandoned, completing the current exploration drilling program in WA-482-P. Karoon has a 50% equity interest in WA-482-P and is carried for 90% of the cost of the well. Joint venture partner, and operator Quadrant Energy Australia Ltd has the remaining 50% interest. The net cost to Karoon is expected to remain within the USD5 million budget.

11 Aug 2015

No hydrocarbons likely at MZ-1

Pura Vida Energy NL (“Pura Vida”) advises that the MZ-1 exploration well offshore Morocco has drilled through the three prognosed Jurassic fans and the well has reached a final depth of 6,150 metres Sub Sea True Vertical Depth (SSTVD) within Triassic aged sediments and wireline logs are expected to be run shortly. Preliminary results from available drilling data (excluding wireline logs) .... [+ read more] indicate that no oil shows have been encountered. After completion of wireline logging, the well is expected to be plugged and abandoned as planned. Whilst final costs in relation to the well are not yet available, the Company anticipates costs to be in line with budget expectations. The decision was made by the joint venture to deepen the well to 6,150 metres to intersect the Lower Jurassic source rocks and test Jurassic Fan-3, which has provided valuable information and the ability to fully calibrate all data prior to selection of the location of the second well. Pura Vida’s Managing Director, Mr Damon Neaves commented: “MZ-1 is Pura Vida’s first exploration well and although this result is a set-back, we will now renew our efforts in pursuing the prospectivity in the Mazagan permit with the benefit of the information we have gained from this well. Mazagan represents a large acreage position containing multiple play types and prospects, what we’ve learned from MZ-1 will help us define the best prospect for our next well on the Mazagan permit. We congratulate the Operator for safely and efficiently completing the MZ-1 deep water well. Pura Vida has built a diversified portfolio that ensures a pipeline of future opportunities to create value for our shareholders.” With regards to a second well, PXP Morocco BV, a subsidiary of Freeport-McMoRan Oil & Gas as Operator of the Mazagan permit (Operator), entered into a rig share agreement with Kosmos Energy Ventures for two well slots with the Atwood Achiever deep water drillship to drill two wells in the Mazagan permit. Pura Vida has been advised by the Operator that it has agreed with Kosmos to cancel the second slot under those arrangements. Rates for deep water drillships have fallen sharply since the Atwood Achiever was contracted and the Operator has cancelled the second slot under the rig share agreement in order to contract another vessel to take advantage of the current weakness in market conditions for rigs with the aim to reduce the cost of the second well. 2 Under the farmin agreement between the Operator and Pura Vida entered into in January 2013, the drilling of the second well must be commenced by no later than September 2016. If the joint venture is successful in securing a drillship at a lower rate, the risk of the cost of the two wells exceeding the US$215 million limit on carry under the farmin agreement will be reduced. This will also have the benefit of reducing Pura Vida’s reliance (if any) on the option for an additional carry in excess of the US$215 million limit, thereby reducing the risk that Pura Vida’s equity in the permit will be diluted

11 Aug 2015

Lundin set to spud Neiden prospect

Lundin Norway AS (“Lundin”) has received consent to drill exploration well 7220/6-2 in the Barents Sea. Lundin is the operator for production licence 609 in block 7220/6 in the Barents Sea. Exploration well 7220/6-2 is to be drilled in a prospect called Neiden. Drilling is scheduled to begin in mid-August 2015 at the earliest and estimated to last 40 days. .... [+ read more]

10 Aug 2015

Maersk Drilling secures contract for 'Maersk Giant'

Maersk Drilling has been awarded a new contract for the jackup rig Mærsk Giant with Danish energy company DONG Energy. The firm contract covers 150 days of work on the Nini and Siri field in the Danish part of the North Sea. The estimated contract value is USD16m. The contract is in direct continuation of the current contract with Talisman keeping .... [+ read more] Maersk Giant employed until March 2016. “We are very pleased to continue our good corporation with DONG Energy, one of our key customers in the North Sea,” says Claus V. Hemmingsen, CEO in Maersk Drilling and member of the Executive Board in the Maersk Group and continues: “In order to navigate the low visibility in the current market, it is essential that we reduce our exposure by securing a solid contract backlog. Therefore, it is also rewarding to see that we secure employment for the Mærsk Giant, which otherwise would have been stacked.”

5 Aug 2015

Lundin successful with Edvard Grieg appraisal

Lundin Petroleum AB (“Lundin”) is pleased to announce that its wholly owned subsidiary Lundin Norway AS (“Lundin Norway”) has completed the drilling and logging of appraisal well 16/1-23 S on the Edvard Grieg field in the Norwegian North Sea. The well was located in PL338 and was drilled approximately 2.4 km southeast of the Edvard Grieg platform location. The objectives of .... [+ read more] the well were to further delineate the south eastern part of the Edvard Grieg field southwestwardly from last year’s successful appraisal well 16/1-18 in order to optimise the drainage strategy and to determine the best possible location for production wells in this area. The well was also testing incremental resource potential in this part of the field. The well encountered a 66 metres gross oil column in pebbly sandstone with medium to good reservoir quality. Extensive data acquisition and sampling is currently ongoing with the initial data results appearing very promising with regard to additional in-place volumes. The integration of these positive well results will be used to optimise the drainage strategy and to determine the best possible location for production wells in this area. Ashley Heppenstall, President and CEO of Lundin Petroleum, comments: “The Edvard Grieg southeast appraisal well has been successful. This well, together with last year’s appraisal well in the same area of the field, will in my opinion result in an increase to the Edvard Grieg reserves at the end of this year. The low incremental cost of developing such barrels will add value to the Edvard Grieg asset.” This is the tenth exploration/appraisal well in PL338 of which seven have been drilled on the Edvard Grieg field. The licence was awarded on 17 December 2004 (APA 2004). The well was drilled to a vertical depth of 2,043 metres below the sea surface and terminated in granite basement. The well will be permanently plugged and abandoned. Water depth at the site is 108 metres. The well was drilled by the jack-up rig Rowan Viking which will return to the Edvard Grieg platform to continue drilling of production and injection wells. Lundin Norway is the operator of PL338 with 50 percent working interest. The partners are OMV Norge AS with 20 percent working interest, Statoil Petroleum AS with 15 percent working interest and Wintershall Norge AS with 15 percent working interest.

4 Aug 2015

Otto spuds Hawkeye-1

Otto Energy Ltd (“Otto”) has provided the following update on the drilling of the Hawkeye-1 exploration well, offshore Palawan Basin in the Philippines as at 0600 hours (AWST) on 3rd August 2015. Progress The Hawkeye-1 exploration well was spud at 1610 hours (AWST) on 31st July 2015. The 36” conductor was run to 1,906 metres and the 26” hole subsequently drilled .... [+ read more] to 2,449 metres. Current operations are to cement the 20” casing string. Forward Plan The forward plan is to connect the blow-out preventer to the wellhead and pressure test before commencing to drill the 17 ½” hole to just above the primary target reservoir. The next update will be provided once the 12 ?” section is drilled into the primary target reservoir, anticipated to occur about two weeks from now. The Hawkeye-1 exploration well will be plugged and abandoned upon completion of drilling and logging. All measurements are from the rig rotary table.

30 Jul 2015

'Maersk Venturer' arrives at Philippines drilling location

Red Emperor Resources NL (“Red Emperor”) is pleased to announce that the load-out of the Maersk Venturer drilling rig has been completed with the vessel now at the Hawkeye drilling location. Drilling will commence over the coming weekend once the rig has been accurately secured over the required drilling location. As one of the most modern and advanced drillships in the .... [+ read more] world, the Maersk Venturer has the required capability to drill the Hawkeye-1 exploration well, with the drilling program expected to last 23 days. The exploration well has been designed to reach the top of target reservoir approximately 1,000m below the sea bed floor and intersect the gas oil contact to prove or otherwise the presence of the oil leg. Red Emperor intends to update the market weekly on the progress of operations.

29 Jul 2015

MZ-1 exploration well disappoints in Morocco

Pura Vida Energy NL (“Pura Vida”) advises that the MZ-1 exploration well has reached a depth of 4,653 metres within the Lower Cretaceous and that wireline logs have been run to evaluate the entire open hole section of the well. Preliminary results from all of the data gathered to date indicates that there is no effective reservoir in either of the .... [+ read more] secondary objectives in the Cenomanian and Aptian intervals and there were no oil shows encountered. Current operations include running casing, prior to drilling ahead to the firm Total Depth (TD) of 5,600 metres in the Jurassic, to test the primary objectives of the basin floor fans, Fan-1 and Fan-2. After drilling through these targets a decision will be made whether to deepen the well to 6,150 metres to test a third Jurassic fan, Fan-3. Managing Director, Mr Damon Neaves commented: “We are disappointed that the well failed to encounter reservoir in the secondary objectives in the Cretaceous, however we expect to intersect the primary targets in the Jurassic and look forward to reporting those results shortly.”

29 Jul 2015

Anadarko confirms discovery with Kronos well

Anadarko continues an active deepwater exploration program. The company's first well, Kronos, in the frontier basin offshore Colombia, encountered 130 to 230 net feet of natural gas pay in the upper objective, proving the presence of a working petroleum system and validating the company's geologic and seismic interpretations. Drilling is ongoing toward the deeper objective before mobilizing the rig to drill .... [+ read more] the Calasu prospect, which is also located in the 4.5-million-acre Grand Fuerte Block, approximately 100 miles northeast of the Kronos well.

29 Jul 2015

Petronas spuds Irish exploration well

Lansdowne Oil & Gas Plc (“Lansdowne”), has announced that the operator of the SEL 4/07 licence in the north of the Celtic Sea spudded the wildcat on the Midleton prospect in the early hours of Wednesday morning with the semi-submersible Ocean Guardian. The well is scheduled to take approximately 20 to 30 days to drill, with Petronas subsidiary Kinsale Energy funding .... [+ read more] 100% of the drilling costs. Midleton is estimated to hold potential for 330 billion cubic feet of gas initially in-place from the same Lower Cretaceous ‘A’ sands that are already producing at Kinsale Head.

27 Jul 2015

Maersk Drilling announces contract extension in Norway

Maersk Drilling has been awarded a contract extension for the jackup rig Mærsk Innovator with ConocoPhillips Norway for work on the Eldfisk field, part of the greater Ekofisk area, offshore Norway. The duration of the contract extension is 16 months. The extension is in direct continuation of the current contract expiring in February 2017, thus keeping the rig continuously contracted until .... [+ read more] June 2018. The estimated value of the contract extension is USD142m. “We are very pleased to see the Mærsk Innovator continue to work for ConocoPhillips,” says Claus V. Hemmingsen, CEO in Maersk Drilling and member of the Executive Board in the Maersk Group. Mærsk Innovator has been working for ConocoPhillips since 2010.

27 Jul 2015

Yinka Folawiyo Petroleum (YFP) spuds Aje-5 well in Nigeria

Panoro Energy ASA ("Panoro"), the independent E&P company with assets in Nigeria and Gabon, is pleased to announce that drilling has commenced on the Aje-5 production well on the OML 113 license, offshore Nigeria. The well is being drilled with the Saipem Scarabeo 3 semi-submersible drilling rig. Aje is an offshore field located in the western part of Nigeria in the .... [+ read more] Dahomey Basin close to the border with Benin. The field is situated in water depths ranging from 100 to 1,000 metres about 24 km from the coast. Panoro Energy holds a 6.502% participating interest in OML 113 (with a 12.1913% revenue interest and 16.255% paying interest in the Aje Field). The Aje Field contains hydrocarbon resources in sandstone reservoirs in three main levels - a Turonian gas condensate reservoir, a Cenomanian oil reservoir and an Albian gas condensate reservoir. The Aje-5 well is being drilled from a seabed location close to Aje-4 in 300 metres water depth. The well will be drilled as a deviated well targeting a location close to the Aje-2 subsurface location where that well encountered and tested high quality oil-bearing Cenomanian reservoir. Following drilling, the Aje-5 well will be completed as a subsea oil production well. The drilling and completion for Aje-5 is expected to take approximately 70 days. Following this the rig will be used to re-enter the existing Aje-4 well to complete it as a second Cenomanian subsea oil production well. Installation of the production manifold, flowlines, umbilicals and risers will take place in Q4 2015 after which the FPSO vessel the ‘Front Puffin’ will be installed and commissioned. Production is expected to commence by year end 2015 at an initial anticipated production flow rate of approximately 1,100 bopd, net to Panoro from these two wells, in accordance with the first phase of the approved Field Development Plan.

24 Jul 2015

NPD confirm Haribo prospect dry well

Edison Norge AS, operator of production licence (PL) 616, is in the process of completing the drilling of wildcat well 2/11-11. The well was drilled about seven kilometres southwest of the Valhall field and about five kilometres west of the Hod field in the North Sea. The primary exploration target for the well was to prove petroleum in Upper Cretaceous .... [+ read more] chalk rocks (the Hod formation). Well 2/11-11 encountered about 330 metres of reservoir rocks in the Hod formation with poor reservoir quality. The well is dry. Data acquisition and sampling have been carried out. This is the first exploration well in production licence 616. The licence was awarded in APA 2011. Well 2/11-11 was drilled to a vertical depth of 3388 metres below the sea surface and was terminated in the Hidra formation (Upper Cretaceous). Water depth at the site is 68 metres. The well will now be permanently plugged and abandoned. Well 2/11-11 was drilled by the Transocean Searcher drilling facility, which will now be laid up.

24 Jul 2015

Statoil announces discovery at Julius

Statoil Petroleum AS, operator of production licence 146, is in the process of concluding the drilling of wildcat well 2/4-23 S. The well was drilled about 17 kilometres northeast of the Ekofisk field, near the 2/4-21 (King Lear) discovery in the southern part of the North Sea. The primary exploration target for the well was to prove petroleum in Upper .... [+ read more] Jurassic reservoir rocks (the Ula formation) and Middle Jurassic reservoir rocks (the Bryne formation), as well as to delineate the 2/4-21 discovery (King Lear), which was proven in Upper Jurassic reservoir rocks (the Farsund formation) in the summer of 2012. Before well 2/4-23 S was drilled, the operator's resource estimate for King Lear was between 11 and 32 million standard cubic metres of recoverable oil equivalents. The secondary exploration target for 2/4-23 S was to prove petroleum in Upper Triassic reservoir rocks (the Skagerrak formation). In the primary exploration target, the well encountered 41 metres of gas/condensate-filled sandstone rocks in the Ula formation, with moderate reservoir quality. The petroleum/water contact was not encountered. Preliminary estimates place the size of the discovery at between 2.5 and 12 million Sm3 of recoverable oil equivalents. The well also encountered 30 gross metres of water-filled sandstone with poor reservoir quality in the Bryne formation. In addition, the well encountered a 20-metre thick gas/condensate column in the Farsund formation, in two zones of five metre thick reservoir rocks with moderate/good reservoir quality, which confirmed pressure communication with the 2/4-21 King Lear discovery. Delineation of the 2/4-21 discovery will not lead to any change in the resource estimates. The Skagerrak formation had poor reservoir quality and was water-filled. The well was not formation-tested, but extensive data acquisition and sampling have been carried out. The licensees will assess the discoveries together, with a view toward an optimal development. This is the fourteenth exploration well in production licence 146, which was awarded in the 12th licensing round. Well 2/4-23 S was drilled to a vertical depth of 5548 metres below the sea surface, and was terminated in sandstone in the Skagerrak formation in the Upper Triassic. Water depth at the site is 68 metres. The well will now be permanently plugged and abandoned. Well 2/4-23 S was drilled by the Mærsk Gallant, which will now proceed to PL 018 to do well work on the Eldfisk field in the North Sea.

24 Jul 2015

Paragon Offshore delays delivery of 'Prospector 6'

Paragon Offshore Plc (“Paragon”) today announced that the company’s wholly-owned subsidiary has signed an agreement with Shanghai Waigaoqiao Shipbuilding Co., Ltd. to extend the delivery date of the high-specification Prospector 6 to April 15th. 2016. Under the terms of the agreement, no payments are due to the shipyard until the delivery date and upon completion of the delivery protocol. .... [+ read more]

24 Jul 2015

Paragon Offshore closes sale & leaseback transaction

Paragon Offshore Plc ("Paragon") today announced that certain wholly owned subsidiaries of the company, which were part of the company's acquisition of Prospector Offshore Drilling S.A. ("Prospector"), have closed the combined USD300 million sale-leaseback financing facility that was announced on June 4th, 2015. Net of fees and expenses, Prospector received net proceeds of approximately USD292 million. Both the Prospector 1 .... [+ read more] and Prospector 5 will now be leased back to Paragon for a five-year period.

21 Jul 2015

Dry well at Haribo prospect in Norway

The Haribo exploration well has been drilled to total depth without encountering hydrocarbons. The well will now be plugged and abandoned. Noreco Norway AS (“Noreco Norway”), part of Norwegian Energy Company ASA group, holds a 20% interest in the licence. Spudded on 21st June 2015 the well was drilled by the semi-submersible drilling rig Transocean Searcher on the Haribo prospect, which .... [+ read more] is located 10 km south west of the Valhall Field in the Norwegian part of the North Sea. The partners in Licence PL616 include Edison Norge (operator with 25%), Noreco Norway (20%), Concedo (20%), Lime Petroleum Norway (15%), North Energy (15%) and Skagen 44 (5%).

20 Jul 2015

Karoon releases Levitt-1 update

Karoon Gas Australia Ltd (“Karoon”) is pleased to announce that the Levitt-1 exploration well in WA-482-P Carnarvon Basin, offshore Western Australia was drilling ahead in the 12-1/4” hole section at a depth of 2,918 mRT. Since the 6th July 2015 Progress Report No 1, the 17-1/2” hole section was drilled to a depth of 2,099 mRT where the 13-5/8” casing was .... [+ read more] run and cemented in place at 2,094 mRT. Blowout Preventer installation and testing was then completed, the casing shoe drilled out and drilling ahead commenced in the 12-1/4” hole section. The Ocean America semi-submersible drilling rig is being used to drill the well which is targeting a net unrisked prospective resource best estimate of 110mmbbls (gross 220mmbbls) . Total depth is expected to be reached during early August. Levitt-1 is designed to test the presence of a working petroleum system generating from the Wigmore sub-basin.

17 Jul 2015

ConocoPhillips cancels 'ENSCO DS-9' contract

Effective today, ConocoPhillips has informed Ensco Plc (“Ensco”) that it has issued a notice of termination for the three-year ENSCO DS-9 drillship contract. Under the terms of the contract, ConocoPhillips is obligated to pay Ensco termination fees monthly for two years equal to the operating day rate of approximately USD550,000, which may be partially defrayed should Ensco re-contract the rig within .... [+ read more] the next two years and/or mitigate certain costs during this time period while the rig is idle and without a contract. ConocoPhillips is also contractually obligated to reimburse certain costs that Ensco incurs due to the termination of the contract for ConocoPhillips’ convenience. Given these contract terms, Ensco does not anticipate a material negative impact to its financial results for 2015 and 2016 as a result of this termination. ENSCO DS-9 was recently delivered and had been scheduled to commence its initial drilling contract for ConocoPhillips in the fourth quarter of this year.

17 Jul 2015

Maersk Drilling secures five year extension in Azerbaijan

Maersk Drilling has been awarded a five-year contract extension for the semi-submersible Heydar Aliyev (Maersk Explorer) rig with BP Exploration (Shah Deniz) Limited acting as Operator of the Shah Deniz field . The rig will continue working on the development of the Shah Deniz field in the Caspian Sea offshore Azerbaijan. The extension is in direct continuation of the current .... [+ read more] contract ending May 2016 and extends the contract until May 2021. The estimated value of the contract extension is up to USD523m. “We are very pleased with the extension for the Heydar Aliyev rig and look forward to continue our long standing cooperation with BP,” says Claus V. Hemmingsen, CEO in Maersk Drilling and member of the Executive Board in the Maersk Group, and continues: “With this contract we continue to build our contract backlog providing further revenue visibility. It is very encouraging that we continue to build backlog in this very challenging market.”

16 Jul 2015

'COSLProspector' spuds first well in South China Sea

China Oilfield Services Limited (“COSL”) said its deepwater drilling rig COSLProspector recently has commenced drilling operation for its first oil well in the deep water regions in South China Sea. In order to ensure smooth completion of this inaugural drilling operation, the Company made thorough pre-drilling preparations. This operation is carried out for an oil well sitting at a water depth .... [+ read more] of 1,289 meters, and a designed drilling depth of the rig at 3,626 meters. COSLProspector is a deepwater semi-submersible drilling rig equipped with Dynamic Position System with a maximum operation water depth of 1,500 meters and a maximum drilling depth of 7,500 meters. This rig has met requirements by both Det Norske Veritas (“DNV”) and NORSOK standards for offshore drilling platforms. This rig has met requirements to operate under freezing temperature, environmental-friendly and low temperature conditions, capable of performing operations in waters under extreme conditions. It can adapt to 90% of the water conditions in the world. Smooth operation of COSLProspector provides leading technology and equipment support to COSL’s participation in competition in the international deepwater drilling market.

16 Jul 2015

CIMC Raffles cuts steel on Sinopec newbuild jackup

On 16th July 2015, CIMC Raffles struck first steel at its CIMC Raffles Yantai shipyard in China on a new 90 meter jackup rig for the Sinopec Group. The jackup has been designed by the Sinopec Drilling Technology Research Institute whist CIMC Raffles was responsible for detailed design, producing design and construction. Upon completion the unit will be managed by SINOPEC .... [+ read more] Shengli Offshore Drilling Company (“SLODC”), with an operating depth of 91.4 meters and a maximum drilling depth of 9,144 meters.

15 Jul 2015

Wintershall given approval to spud the Syrah prospect

Wintershall has received consent to drill exploration well 35/11-18 in the North Sea. Wintershall is the operator for production licence 248 in block 35/11 in the North Sea. The formation into which the well will be drilled is designated 'Syrah'. Drilling is scheduled to begin in August 2015 and estimated to last 48 days, depending on whether a discovery is made. .... [+ read more]

15 Jul 2015

Wintershall comes up dry at Zeppelin

Wintershall Norge AS, operator of production licence 734, is in the process of completing the drilling of wildcat well 10/4-1. The well was drilled about 35 kilometres southeast of the Yme field in the North Sea. The primary exploration target for the well was to prove petroleum in Upper Jurassic reservoir rocks (the Sandnes formation) and in Middle Jurassic reservoir .... [+ read more] rocks (the Bryne formation). The secondary exploration target was to prove petroleum in Upper Permain reservoir rocks. Well 10/4-1 encountered approx. 90 metres of reservoir rocks in the Sandnes and Bryne formations with good reservoir quality. The well did not encounter a reservoir in Permian rocks. The well is dry. Data acquisition and sampling have been carried out. This is the first exploration well in production licence 734. The licence was awarded in APA 2013. Well 10/4-1 was drilled to a vertical depth of 2348 metres below the sea surface and was terminated in rocks from the Late Permian Age. Water depth at the site is 98 metres. The well will now be permanently plugged and abandoned. Well 10/4-1 was drilled by the Borgland Dolphin drilling facility, which will now proceed to drill wildcat well 6507/3-11 S in production licence 650 in the Norwegian Sea, where E.ON E&P Norge AS is the operator.

15 Jul 2015

Songa receives notice of arbitration from Daewoo

Songa Offshore SE (“Songa”) has announced that Daewoo Shipbuilding and Marine Engineering Co. Ltd. (“DSME”) has delivered notices of arbitration in respect of the construction contracts for Songa’s Cat D semisub rigs. No details regarding the dispute have been included in the notices by DSME. As informed by Songa in its first quarter 2015 interim financial report, DSME has experienced significant .... [+ read more] delays and cost overruns during the Cat D project. Irrespective of that, the Songa continues to be of the view that any attempt to recover cost overruns is of no merit and will defend its position vigorously.

14 Jul 2015

Maersk Drilling retires 'Maersk Endurer'

Maersk Drilling has decided to decommission the Maersk Endurer rig from its operational fleet and recycle the rig at Zhoushan Changhong International Ship Recycling in China. “Given the current market situation and the oversupply of drilling rigs in the offshore market, there is a strong need to retire older rigs. Therefore, Maersk Drilling has decided to decommission its oldest rig in .... [+ read more] the fleet, Maersk Endurer,” says Morten Pilnov, Head of Global Sales in Maersk Drilling. The rig will be transported to Zhoushan Changhong International Ship Recycling in mid-July 2015, and it will take approximately 15 weeks to recycle the rig. “It is Maersk Drilling’s ambition to decommission Maersk Endurer in a safe and responsible way with minimal environmental impact. Therefore, Maersk Drilling has chosen Zhoushan Changhong International Ship Recycling to recycle Maersk Endurer. Maersk Drilling has furthermore engaged Sea2Cradle to carry out inspections and supervise the entire process,” Morten Pilnov explains and continues: “We chose this option because we consider it to be the safest and most cost-effective approach, with the lowest environmental risks. Zhoushan Changhong International Ship Recycling is a state-of-the-art rig recycling facility, and the facility complies with the Hong Kong International Convention for the Safe and Environmentally Sound Recycling of Ships and the European Union Ship Recycling Regulation.” The Maersk Endurer is Maersk Drilling’s oldest rig in the fleet. The rig is a jack-up rig, and it was built in 1984, and has latest been working offshore Cameroon.

14 Jul 2015

Paragon Offshore embarks upon wave of cold stacking

Paragon Offshore Plc (“Paragon”) has announced it has taken the decision over the past month to cold stack eight jackup rigs. The announcement follows the company’s release of its updated fleet report in which Paragon has laid out plans to cold stack four jackups in the USA following their move from Mexico (B301, L1113, L781 and M821). In addition to these .... [+ read more] four units, the company has cold stacked the L785 jackup in Malaysia, the L783 jackup in Cameroon and the L1116 and M531 units in the USA. The eight jackups have a combined average age of 37 years and are at the older end of the operational rig fleet spectrum. This wave of cold stacking comes as these units concluded their existing contracts and with no future contracts on the horizon, Paragon has taken the decision to remove them from its active fleet.

13 Jul 2015

KS Drilling delay delivery of newbuild jackup

KS Energy Limited (“KS Energy”) has announced that one of the company’s subsidiaries KS Drilling has reached an agreement with COSCO shipyard to delay the delivery of a newbuild jackup rig. The unit in question is hull number 408 (KS Orient Star 2), which was ordered from the shipyard in 2011. The unit was originally scheduled to be delivered in Q1 .... [+ read more] 2014, and was then reported to have been delivered in January 2015; however, KS Drilling has now pushed this back until 30th April 2016. Under the terms of the new agreement KS Drilling are entitled to take delivery of the rig at any time prior to the 30th April 2016, so long as COSCO shipyard receives full payment five working days in advance. KS Drilling and COSCO shipyard have also, mutually agreed that: in the event that either party receives an offer from a third party under which both parties could recover their respective costs, either party shall be entitled to sell the rig.

13 Jul 2015

Lundin gets drilling permit for Neiden prospect

The Norwegian Petroleum Directorate has granted Lundin Norway AS a drilling permit for well 7220/6-2, cf. Section 8 of the Resource Management Regulations. Well 7220/6-2 will be drilled from the Island Innovator drilling facility in position 72°34’13.13” north and 20°58’19.97” east. The drilling programme for well 7220/6-2 relates to the drilling of a wildcat well in production licence 609. Lundin .... [+ read more] Norway AS is the operator with a 40 per cent ownership interest, and the licensees are Idemitsu Petroleum Norge AS with 30 per cent and RWE Dea Norge AS with 30 per cent. The production licence consists of the blocks/part of blocks 7220/6, 7220/9, 7220/11, 7220/12 and 7221/4. The production licence was awarded in the 21st licensing round in 2011. Wildcat well 7220/6-2 will be the fifth exploration well in production licence 609. This permit is contingent upon the operator having secured all other permits and consents required by other authorities before the drilling starts.

10 Jul 2015

North Atlantic Drilling secures new contract for 'West Phoenix'

North Atlantic Drilling ("NADL") has been awarded a contract extension for the semi-submersible rig West Phoenix by Total E&P UK Limited, commencing mid-March 2016 and securing work for the unit through the end of August 2016. The total revenue potential for the contract extension is approximately USD62 million. A portion of the USD62 million will be paid during the currently anticipated .... [+ read more] idle period from the beginning of September 2015 to the middle of March 2016. The Company has the ability to market the rig for alternate work during this period. As part of the agreement to extend the West Phoenix, the Company has agreed to a dayrate reduction on the current contract effective from June 1, 2015 until its expected conclusion at the end of August 2015, resulting in a reduction to the remaining revenue potential of approximately USD16 million.

8 Jul 2015

Pacific Drilling delays delivery of 'Pacific Zonda'

Pacific Drilling Ltd. (“Pacific”) has announced that the company plans to delay the delivery of its newbuild ultra-deepwater drillship, the Pacific Zonda from September 2015 through to Q1 2016. It is believed that the continued decline in contracting opportunities in the global rig market has influenced this decision; especially as in Q1 2015 Pacific announced that it intended to maintain the .... [+ read more] unit’s delivery schedule, due to its strong construction contract. The decision may have been further impacted by Pacific’s struggle to secure a firm contract for its recently delivered Pacific Meltem drillship, which is currently ready stacked in the USA and has been since December 2014. In the past the rig manager has laid out that the company will not spend money on mobilising a unit to a geographical location where they already have rigs available.

8 Jul 2015

Global Maritime secures mooring work in Australia

Global Maritime Deep Sea Mooring has been awarded a contract for the provision of mooring and rig positioning services to the Australian oil and gas company Woodside. Under the contract with Woodside, Global Maritime Deep Sea Mooring will perform mooring and rig positioning services for semi-submersible drilling unit Ocean Monarch, which is drilling at the Julimar field on the Northwest Shelf, .... [+ read more] Australia. Mobilisation and offshore operations commenced in May 2015. “Winning this contract confirms the importance of flexibility and local presence, with availability of equipment and personnel. We are very pleased that our unique advanced technologies and equipment specifications are highly appreciated by key industry players”, says Managing Director Barry Silver in Global Maritime Deep Sea Mooring Australia. “This is our first contract with Woodside, and we look forward to developing a close cooperation going forward”.

7 Jul 2015

Eni extends 'Atwood Beacon' contract

Atwood Oceanics, Inc. (“Atwood”) announced today that one of its subsidiaries had reached an agreement for a six-month extension of its existing contract with Eni S.p.A. (“Eni”) for the jackup rig, Atwood Beacon. The Atwood Beacon commenced its initial two-year drilling services contract with Eni on December 24th 2013, for operations offshore Italy. The agreement revises the day rate .... [+ read more] to €117,155 (USD129,365), inclusive of equipment upgrade costs, from €135,100 (USD149,180) beginning March 1st, 2015 and extends the Atwood Beacon's firm commitment from December 24th, 2015 through June 2016.

7 Jul 2015

'ENSCO 107' completes drilling operations on Maari Grwoth Project

Horizon Oil (“Horizon”) is pleased to report the successful completion of the Maari Growth Project with the final well, MR10, now in production. The MR10 well has been successfully drilled and completed and, as of 6th July 2015, was flowing approximately 2,000 barrels of oil per day (“bopd”), with daily production of approximately 16,500 barrels of oil per day. The final .... [+ read more] flow rate for MR10 will be optimised by the Operator, OMV New Zealand, based on engineering data collected as the well continues to stabilise. A total of four new production wells were drilled in the Maari Growth Program using the Ensco 107 jackup rig. The operator of the Maari joint venture anticipates the field’s production capacity to increase to approximately 20,000 bopd with the optimisation of production from MR10 and an upcoming 2015 work-over campaign. The Ensco 107 is now being prepared for demobilisation from the Maari Field. The Maari joint venture’s work-over unit (“WOU”) equipment is being prepared for scheduled load out to the wellhead platform in late July 2015. The WOU will be used to carry out maintenance workovers and other activities such as adding perforations to further enhance production. The work-over campaign is scheduled will commence after the demobilisation of the Ensco 107.

7 Jul 2015

'KS Java Star' contract terminated

KS Energy Ltd. has announced that the contract awarded to its KS Java Star jackup rig on the 6th March 2015 with a value of USD7.2 million has now been cancelled. The contract was cancelled following various meetings with the client, and their request to delay the beginning of the contract. The client chose to terminate the contract as both parties .... [+ read more] were unable to agree upon a new contract start date.

6 Jul 2015

Global Maritime to provide mooring for 'Ocean America'

Global Maritime Deep Sea Mooring has been awarded a contract for the provision of mooring and rig positioning services for the Australian oil and gas company Quadrant energy. Under the contract with Quadrant Energy, Global Maritime Deep Sea Mooring will perform mooring and rig positioning services for both semi-submersible and jack-up operations on the Northwest Shelf, Australia. The contract will begin .... [+ read more] with Quadrant Energy’s use of the Ocean America for drilling operations on the Levitt-1 well.

6 Jul 2015

Levitt-1 well spudded in Australia

Karoon Gas Australia Ltd (“Karoon”) is pleased to announce the commencement of the high impact Levitt-1 exploration well in WA-482-P Carnarvon Basin, off-shore Western Australia. Levitt-1 spudded at 1230 AEST on 4th July 2015. The shallow hole section has been drilled 73 metres, in a water depth of 1,163 metres to the current depth of 1,262 mRT and the conductor casing .... [+ read more] has been set. Preparations are underway to commence drilling in the 17-1/2” hole section later today. The Ocean America semisubmersible drilling rig is being used to drill the well which is targeting a net unrisked prospective resource best estimate of 110mmbbls (gross 220mmbbls). Total depth is expected to be reached during early August.

6 Jul 2015

'Maersk Discoverer' finished well 62 days ahead of time

At the beginning of May 2015, the crew on-board the Maersk Discoverer reached a great milestone when they finalised their latest well two months ahead of time. The well was another East Nile Delta success for BP, discovering 50 m of gas pay in high-quality Oligocene sandstones. On 5th May, Maersk Discoverer completed the deepest well ever drilled in Egypt and .... [+ read more] the longest ever drilled in the Mediterranean Sea. What makes the well an even greater success is that it was drilled in 234 days, which was a staggering 62 days ahead of BP’s AFE target, thus creating a substantial cost saving.

3 Jul 2015

Vantage respond to reports surrounding 'Titanium Explorer' contract

Vantage Drilling Company ("Vantage") has challenged reports alleging that the arrest of a former Petrobras International Director was tied in some way to the Company's contract with Petrobras for the Titanium Explorer. "Several hundred contracts were signed by this former Director, which in Vantage's case, was after the parent board of Petrobras had approved the contract," said Paul Bragg, Chairman and .... [+ read more] CEO of Vantage. Vantage is fully performing under the contract and found no evidence that would substantiate any allegation of improper activity by Vantage in connection with the award of the contract. Paul Bragg additionally commented, "Vantage has always been committed to conducting itself in accordance with the highest standards of business ethics. We do not believe that any inappropriate act was committed by any personnel associated with Vantage. Although we are disappointed that recent news reports have suggested that a former Petrobras International Director was arrested on the suspicion of some form of wrongdoing associated with Vantage, as well as with other companies contracted to Petrobras, we are confident that any suggestion is without merit as it relates to Vantage."

3 Jul 2015

Origin Energy completes Yolla-5 development well

AWE Limited (“AWE”) has announced that the Operator of the BassGas joint Venture in permit T/L1, Origin Energy (“Origin”), has confirmed that the the Yolla-5 development well has reached a Total Depth of 3,384m Measured Depth below Rotary Table (“MDRT”). Yolla-5 has successfully intersected the primary reservoir targets located in the Paleocene EVCM sands. Good continuity of reservoir quality and thickness .... [+ read more] is observed between Yolla-5 and Yolla-6. The well has been logged, evaluation of results is ongoing and preparations are in place to case and complete the well before being commissioned for production and tied-in to the Yolla facility. The Yolla-5 and Yolla-6 development wells have been drilled using the West Telesto jack up rig and represent Stage 2 of the BassGas Mid Life Enhancement (MLE) project. The BassGas project consists of the Yolla offshore well head platform connected by pipeline to the gas processing facility at Lang Lang, Victoria.

2 Jul 2015

Det Norske completes two Ivar Aasen appraisal wells

Det norske oljeselskap AS, operator of the Ivar Aasen field, has completed the drilling of appraisal wells 16/1-22 S, 16/1-22 A and 16/1-22 B. The field is located in the central part of the North Sea and was proven in 2008. The size of the field prior to drilling the appraisal wells was 24 million standard cubic metres (Sm3) of recoverable .... [+ read more] oil, 1 million Sm3 of recoverable condensate and 4.5 billion Sm3 of recoverable gas. The objective of well 16/1-22 S was to investigate reservoir rocks and reservoir quality, as well as secure depth control along the west flank of the field in Middle Jurassic to Upper Triassic reservoir rocks (the Hugin, Sleipner and Skagerrak formations) in order to optimise well sites with a view to the drainage strategy. Sidetracks 16/1-22 A and 16/1-22 B were drilled 1000 metres northeast and 1350 metres north, respectively, of 16/1-22 S in order to investigate reservoir rocks and perform additional data acquisition. 16/1-22 A also aimed to investigate an underlying seismic anomaly. 16/1-22 S encountered a 3-metre oil column in sandstone of good to very good reservoir quality in the Skagerrak formation. The oil is saturated with a gas/oil ratio of about 160 Sm3/Sm3, as is the case otherwise in the western part of the field (16/1-11, 16/1-11 A and 16/1-9). The oil/water contact was not encountered, but was calculated at about 2435 metres, which is deeper than the previously calculated oil/water contact for the Skagerrak formation (16/1-11 A). 16/1-22 A encountered a total oil column of about 55 metres in the Skagerrak formation, 30 metres of which was in sandstone of varying reservoir quality, from moderate to very good. The oil/water contact was not encountered. The seismic anomaly is linked to the top of a total oil column of about 25 metres in underlying sandstone (alluvial fan), 15 metres of which had moderate reservoir properties. The oily part of the alluvial fan is not included in the field's previously reported reserves. 16/1-22 B encountered a total oil column of about 45 metres in the Skagerrak formation, 25 metres of which was in sandstone of good to very good reservoir quality. The oil/water contact was not encountered. None of the wells were formation-tested, but comprehensive data collection and sampling was conducted. The results have yielded valuable information as regards the final location of production and water injection wells. Gas was not encountered in the wells. The Plan for Development and Operation (PDO) of the Ivar Aasen field was submitted to the Ministry of Petroleum and Energy on 21 December 2012. Wells 16/1-22 S, 16/1-22 A 16/1-22 B were drilled to measured depths of 2640, 2896 and 3215 metres, respectively, and vertical depths of 2562, 2468 and 2501 metres below the sea surface. They were all terminated in the Skagerrak formation in the Upper Triassic. The wells have been permanently plugged and abandoned. Water depth at the site is 113 metres. The wells were drilled by the Maersk Interceptor drilling facility, which will now continue production drilling on the Ivar Aasen field once the platform's jacket has been installed.

2 Jul 2015

Premier receives approval to drill Myrhauk prospect

Premier Oil Norge AS (“Premier”) has received consent to drill exploration well 3/7-10 S in the southern part of the North Sea. Premier is the operator of production licence 539 in block 3/7 in the North Sea. The formation to be drilled into is called Myrhauk and is around 240 kilometres from the nearest mainland at Lista. Drilling is scheduled to .... [+ read more] begin in August 2015 and estimated to last 62 days, depending on whether a discovery is made. The well will be drilled by Mærsk Guardian which is a jack-up mobile drilling facility. It is owned and operated by the A.P. Møller-Mærsk Group. It was built in Japan by Hitachi and completed in 1986.

2 Jul 2015

Otto Energy to mobilise 'Maersk Venturer' towards end of July

Otto Energy Ltd (“Otto”) is pleased to announce it has issued Maersk Drilling with formal notice in respect of the mobilisation of the Maersk Venturer drillship to the Hawkeye-1 exploration well location. Mobilisation to the drilling location will commence on 31st July 2015 and is expected to take around 1 to 2 days, with drilling operations to commence upon arrival of .... [+ read more] the rig on location. Drilling is expected to take around 23 days at the location.

2 Jul 2015

NPD approves Myrhauk prospect drilling

The Norwegian Petroleum Directorate (NPD) has granted Premier Oil Norge AS a drilling permit for well 3/7-10 S, cf. Section 8 of the Resource Management Regulations. The well will be drilled from the Mærsk Guardian drilling facility in position 56°27’10.62’’ north and 4°04’46.18’’ east. The drilling programme for well 3/7-10 S relates to the drilling of a wildcat well in .... [+ read more] production licence 539. Premier Oil Norge AS is the operator with an ownership interest of 40 per cent. The other licensees are Suncor Energy Norge AS (20 per cent), DEA Norge AS (12 per cent) and Ithaca Petroleum Norge AS (eight per cent). Production licence 539 was awarded in APA 2009. The area in the production license is located in the southern part of the North Sea, in the western part of the border block 3/7. Well 3/7-10 S is the first exploration well in this production licence. The permit is contingent on the operator securing all other permits and consents required by other authorities before the drilling activity commences.

1 Jul 2015

Statoil makes minor discovery near Gina Krog

Statoil Petroleum AS, operator of the Gina Krog Unit, has completed the drilling of wildcat well 15/6-13 and appraisal wells 15/6-13 A and 15/6-13 B. The wells were drilled about 250 kilometres west of Stavanger and directly northeast of the Gina Krog field. The objective of well 15/6-13 was to prove commercial petroleum volumes in Middle Jurassic reservoir rocks (the .... [+ read more] Hugin formation), acquire sufficient data to avoid further delineation, investigate the size of the discovery, the properties and continuity of the reservoir rocks, as well as determine the petroleum properties. The objective of sidetracks 15/6-13 A and 15/6-13 B was to delineate the discovery as regards the likelihood of deeper oil and shallower gas on the structure. 15/6-13 has two separate oil columns, 13 and 3 metres of which are in sandstone with moderate to good reservoir properties in the Hugin formation and upper part of the Sleipner formation. The oil/water contact was not encountered. 15/6-13 A encountered seven and nine metres of sandstone with moderate reservoir quality in the Hugin and Sleipner formations, both aquiferous. The aquiferous sandstone in the Hugin formation is presumed to be in pressure communication with the oil zone in 15/6-13. 15/6-13 B shows an overall gas column of about 60 metres, of which 7 metres are in sandstone with moderate reservoir quality in the Hugin formation and 26 metres in sandstone with moderate reservoir properties in the Sleipner formation. The underlying sandstone in the Skagerrak formation is tight and aquiferous. For the discovery as a whole, the overall oil and gas column totals about 300 metres, 150 metres for each. Preliminary calculations of the size of the discovery are between one and two million standard cubic meters (Sm3) of recoverable oil equivalents in the Hugin formation, whereas calculations of any additional volumes from the Sleipner formation will require additional assessment for further clarification. None of the wells were formation-tested, but comprehensive data collection and sampling was conducted. The licensees in the Gina Krog Unit will assess the discovery further with a view toward possible development and tieback to the Gina Krog field. Wells 15/6-13, 15/6-13 A and 15/6-13 B were drilled to a measured depth of 3577, 3925 and 3773 metres, respectively, and vertical depths of 3552, 3716 and 3447 metres below the sea surface. They were all terminated in the Skagerrak formation in the Upper Triassic. The wells have been permanently plugged and abandoned. Water depth at the site is 114 metres. The wells were drilled by the Songa Trym drilling facility, which will now move on to drill another Statoil-operated well on the UK shelf.

1 Jul 2015

Statoil suspends 'Scarabeo 5' rig contract

Statoil Petroleum AS (“Statoil”) has decided to suspend the contract associated with the Scarabeo 5 semisub due to overcapacity in its rig portfolio. The suspension will take effect once Scarabeo 5 has completed drilling a well on the Kristin field in the middle of August, and will last until 1st March 2016. Jon Arnt Jacobsen, senior vice president of Procurement at .... [+ read more] Statoil said, “We regret the need to suspend Scarabeo 5, but we will do our utmost to resume our drilling operations earlier than planned at the time of suspending the rig”. This is the second time that Statoil has suspended the contract for the Scarabeo 5 following the suspension that ran form August 2014 until February 2015. Statoil did not announce any details to do with the potential percentage of its current charter rate that the unit will receive whilst under suspension.

30 Jun 2015

Songa Offshore takes delivery of first Cat-D semisub

Songa Offshore has today taken delivery of Songa Equinox from Daewoo Shipbuilding & Marine Engineering (“DSME”) in South Korea. The Songa Equinox will shortly depart South Korea enroute to Norway for commencement of an eight-year drilling contract with Statoil, with its first assignment on the Troll Field on the Norwegian continental shelf. The voyage to Norway will take place in a .... [+ read more] tow-assist mode and the rig will arrive with all third party equipment installed and ready for final acceptance testing. Commencement of drilling operations is expected to take place in Q4 2015. Songa Equinox is a sixth generation, high specification, harsh environment, midwater rig designed for efficient year around drilling, completion, testing and intervention operations in water depths up to 500 meters. The rig is certified DP3 and is equipped with a "state-of-the-art" drill-floor and an efficient layout with improved safety and working environment features. Songa Equinox is the first rig in a series of four Category D rigs specifically built for and contracted to Statoil.

30 Jun 2015

TSC Group exercises options for two newbuild jackups

TSC Group Holdings Limited (“TSC)” is pleased to announce that on 29th June 2015, its wholly-owned subsidiary, Alliance Offshore Drilling (“AOD”) exercised options to build two additional R-550D jack-up rigs at CSSC Huangpu Wenchong Shipyard (“HPWS”) in Guangzhou, China. The contract signing follows the continued positive market response received for the first R-550D rig, AOD1, which is currently in the final .... [+ read more] phase of installation and commissioning at HPWS. The first newbuild hull (H6006) is scheduled for delivery before 31st December 2017, whilst the second (H6007) is scheduled for 30th June 2018. Meeting with the press after the signing ceremony, TSC Chairman, Mr. Jiang Binghua said “We are very pleased with this opportunity which is based on the strong foundation and excellent collaboration established during the AOD1 construction. Today’s R-550D signing signifies TSC and our alliance partner’s abilities to provide a rig for the future which is cost effective and technologically superior.” TSC, through its subsidiary AOD, is committed to achieving excellent standards and quality established during the AOD1 construction to ensure that the two additional R-550D rigs are delivered safely, on time and on budget. Mr. Chen Zhongqian, the Chairman of HPWS, also said today at the contract signing ceremony that “We are committed to a long term strategy on the oil and gas sector and we are firmly of the belief that the R-550D offers the best value for money for the future of jack up rigs.” These projects emphasize the long term commitment and confidence of the strategic alliance partners, HPWS, Zentech and TSC, in promoting HPWS to the forefront of the global offshore marine construction industry. The current R-550D under construction was undocked on 15th May 2015 on schedule with commendable safety and quality standards. Performance of the rig is augmented by the support of experienced professionals on the project management teams.

29 Jun 2015

Northern Offshore reaches agreement with CAMAC

Northern Offshore, Ltd. (“Northern”) today announced a development in its subsidiary Northern Offshore International Drilling Company’s (“NOIDC”) Contract Dispute with Oceanic Consultants Nigeria Ltd., Allied Energy Plc, Erin Energy Corporation (formerly CAMAC Energy Inc.) and CAMAC Petroleum Limited (referred to collectively as the CAMAC PARTIES) related to the contract for the Energy Searcher. NOIDC has reached an agreement with the CAMAC .... [+ read more] PARTIES with respect to the Contract Dispute settling all disputes and claims between NOIDC, NOF and the CAMAC PARTIES. The contract was cancelled by Northern in January 2015.

29 Jun 2015

Northern Offshore set to be combined with Blue Ocean Drilling

The boards of directors of Northern Offshore, Ltd. (“NOF”) and Shandong Offshore International Company Limited (“Purchaser”) are pleased to announce that they have reached agreement on the terms of a recommended cash acquisition of NOF by Shandong Offshore Company Limited (“Bidco”), a wholly owned subsidiary of the Purchaser (“Acquisition”). The Acquisition will be implemented by way of an amalgamation (“Amalgamation”) under .... [+ read more] Bermuda law at an acquisition price of NOK7.59 per NOF share, payable in cash (“Acquisition Price”). The Acquisition Price values NOF’s issued share capital at approximately NOK1.3 billion. The Acquisition is expected to become effective during the first half of August 2015. At the time at which the Amalgamation becomes effective, each NOF share (other than NOF shares held by the Purchaser, Bidco, any other subsidiary of the Purchaser or any subsidiary of NOF, if any) will be converted into the right to receive the Acquisition Price. The board of directors of NOF unanimously recommends that NOF shareholders vote to approve the Acquisition at the SGM. Commenting on the Acquisition, Yu Bing, Director of the Purchaser and Dr. Sun Yuanhui, Chairman of Blue Ocean Drilling Limited, said: “The acquisition of Northern Offshore Ltd. is a positive step in our vision of building a high-performing offshore drilling organization to meet the current and future needs of the Global E&P sector. By retaining the NOF leadership team, when combined with our Blue Ocean Drilling leadership, we will have assembled a highly skilled and experienced team to direct and execute on our strategies as the new Northern Offshore Ltd. going forward. NOF provides proven operating and safety systems, a respected and proven operating organization with an established presence in the North Sea and Asia Pacific, well maintained assets and the most important asset - quality people to execute our strategy. Enhancement of the new NOF fleet is already underway with the combined NOF and Blue Ocean Drilling new–builds; six (6) high specification, deepwater jackups due to be delivered in 2016 through 2018, which will make the new NOF an attractive partner to those E&P companies looking for premium, high specification assets operated by a proven organization whose focus is operations and efficiencies that can contribute to lowering their clients total well costs. We’ll continue to evaluate and act upon further opportunities which meet the technical and financial criteria of the new Northern Offshore Ltd. as we examine ways to further enhance our fleet in an accretive manner.” Commenting on the Acquisition, Gary W. Casswell, President and CEO of NOF said: “This transaction represents a major milestone in Northern Offshore’s previously stated strategy to transform our company to a niche, premium jackup drilling contractor with new, state of the art assets. With the exception of the Norwegian continental shelf, NOF will be able to operate in all major petroleum resource regions around the world. Combining the four (4) under construction high spec jackups of Blue Ocean Drilling with Northern Offshore’s two (2) under construction state of the art jackups with deliveries in 2016 thru early 2018, we will realize organizational synergies and have the opportunity to build additional critical mass in our current operations in the North Sea and Asia Pacific as well as position us to pursue new clients in new areas. Going forward, with the support of our new Board of Directors, we will be opportunistic while remaining fiscally responsible to continue growing the company with the selective acquisition or new construction of additional premium jackup assets. Finally, I would like to acknowledge and express our sincere appreciation for the loyalty and support of all of our past and present shareholders who have helped us reach this new beginning.”

29 Jun 2015

NPD approves E.On Salander prospect drilling

The Norwegian Petroleum Directorate (NPD) has granted E.ON E&P Norge AS a drilling permit for well 6507/3-11 S, cf. Section 8 of the Resource Management Regulations. Well 6507/3-11 S will be drilled from the Borgland Dolphin drilling facility in position 65°48’59.60” north and 7°50’14.0”east. The drilling programme for well 6507/3-11 S relates to the drilling of a wildcat well in .... [+ read more] production licence 650. E.ON E&P Norge AS is the operator with a 60 per cent ownership interest, and Statoil Petroleum AS is the other licensee with a 40 per cent interest. The production licence consists of part of block 6507/3 and was awarded in APA 2011. Wildcat well 6507/3-11 S will be the first well in production licence 650. The permit is contingent upon the operator having secured all other permits and consents required by other authorities before the drilling starts.

26 Jun 2015

Aibel wins contract for 'Deepsea Bergen' SPS

Odfjell Drilling has awarded Aibel Haugesund a contract for yard stay services related to the periodic survey for Deepsea Bergen. The contract has a value of NOK 40m (USD5.1m). The yard stay will take place early in the autumn 2015 and will amongst other cover inspection activities for structure, piping and tanks which must be done while the rig is located .... [+ read more] at yard. The periodic survey and the yard stay are planned according to Odfjell Drilling’s survey strategy minimising the time off hire and the length of the yard stay. Activities related to the periodic survey have been ongoing since early 2014. The yard stay is estimated to 30 days excluding sailing time.

25 Jun 2015

Suncor fails to hit at Niobe prospect

Trapoil has announced that Suncor Energy, the operator of the Niobe prospect in Norway has concluded drilling operations on the prospect. The exploration well was drilled to a depth of 5,005 feet Measured Depth Below Rotary Table ("MDRT") or 4,871 feet True Vertical Depth Sub Sea ("TVDSS") within the Late Jurassic Heather Formation and as such has fulfilled the licence obligation. .... [+ read more] The well achieved its primary target, being the Burns Sandstone Member within the late Jurassic interval. The well penetrated good quality sands although there were no signs of significant hydrocarbons. There are no plans to conduct a drill stem test and the well is to be plugged and abandoned.

24 Jun 2015

'Scarabeo 5' set to complete well 7121/4-G-4 H

The Petroleum Safety Authority (“PSA”) has given Statoil consent to use the Scarabeo 5 mobile drilling facility for drilling and completing well 7121/4-G-4 H. Scarabeo 5 is a type ME 4500 mobile drilling facility and was built by Fincantieri Shipyards in Genoa, Italy in 1990. It is operated by Saipem Norwegian Branch (“Saipem”). It is registered in the Bahamas and classified .... [+ read more] by ABS. Scarabeo 5 was issued with an Acknowledgement of Compliance (AoC) by the PSA in May 2003. Snøhvit is in the Barents Sea in the central part of the Hammerfest Basin, in 310 to 340 metres of water. Snøhvit is a gas field with condensate and an underlying thin oil zone. The Snøhvit Unit comprises the Snøhvit, Albatross and Askeladd structures. The approved PDO for the gas resources includes subsea templates for 19 production wells and one injection well for CO2.

24 Jun 2015

Suncor fails to find hydrocarbons at Mermaid prospect

Suncor Energy Norge AS, operator of production licence 571, has completed the drilling of exploration well 25/10-13 S. The well is dry. The well was drilled in the central part of the North Sea about 5 kilometres west of the Balder field and 200 kilometres northwest of Stavanger. The primary exploration target for the well was to prove petroleum in .... [+ read more] reservoir rocks from the Paleocene (Ty formation) and in the Upper Jurassic (intra Draupne sandstone). The secondary exploration target was to prove petroleum in Lower Triassic reservoir rocks (Smith Bank formation). The well encountered a 35-metre thick layer of sandstone in the Ty formation, and a 44-meter thick layer of Upper Jurassic sandstone, both with good reservoir quality. The well also encountered a 223-metre thick section of the Smith Bank formation, of which about 47 metres is sandstone with moderate to poor reservoir quality. The well is dry. Data acquisition has been carried out. Well 25/10-13 S was drilled to a measured depth of 2925 metres and a vertical depth of 2715 metres below the sea surface, and was terminated in the Triassic (most likely in the Smith Bank formation). This is the first exploration well in production licence 571, which was awarded in APA 2010. Water depth at the site is 119 metres. The well will now be permanently plugged and abandoned. Well 25/10-13 S was drilled by the Borgland Dolphin drilling facility, which will now drill wildcat well 10/4-1 in production licence 734, where Wintershall Norge AS is the operator.

24 Jun 2015

Shell spuds Deep Sleep prospect in US Gulf of Mexico

Freeport-McMoRan Oil & Gas Inc (“Freeport”) has announced that its partner Shell has commenced drilling at the Deep Sleep prospect in blocks 18 and 19 of the Atwater Valley area. Shell spudded the well in 4,253ft of water and plans to drill down to depths of 31,700ft. The drilling is being conducted from the Stena IceMax drillship, which Shell plans to .... [+ read more] send to Canada for drilling operations in the 2nd half of 2015.

24 Jun 2015

Statoil cancels 'COSLPioneer' contract

Statoil has decided to cancel the contract for the COSLPioneer semisub before the expiry date of August 2016. COSLPioneer has been suspended since 8th October 2014 and the unit was meant to finish its suspension period in August 2015, However, Statoil has been unable to find alternative activity for the rig during the intervening period and has now firmly cancelled the .... [+ read more] contract. “We regret the need to have to cancel this contract and wish to emphasise that this is not due to how the rig has delivered,” says supply chain senior vice president, Jon Arnt Jacobsen. “COSL Pioneer and its crew have demonstrated a good safety culture and delivered efficient drilling operations to Statoil. Cancellation is a consequence of overcapacity in the rig portfolio.”

24 Jun 2015

Lundin spuds two new appraisal wells

Lundin Petroleum AB (“Lundin”) has announced that the company’s subsidiary Lundin Norway AS (“Lundin Norway”) has begun drilling its second appraisal well on the Alta field in the Barents sea and has also commenced further appraisal drilling on the Edvard Greig field in the Norwegian North Sea. Meanwhile drilling has also begun on the partner-operated Zeppelin exploration well. The second .... [+ read more] Alta appraisal well (7220/11-3) was spud in PL 609 and is targeting the Permian reservoir. The planned depth of the well is 2,070 metres and the well is being drilled from the Island Innovator. The Edvard Greig appraisal well (16/1-23 S) is located in PL 338 and Lundin Norway plans to spud the well to a total depth of 2,200 metres. Drilling is expected to take around 60 days and is being performed by the Rowan Viking jackup rig. Meanwhile the Borgland Dolphin semisub rig recently spud the Zeppelin exploration well in PL 734. Wintershall is the operator of the well (10/4-1), and believes that Zeppelin holds prospective resources of 152 MMboe. The well is expected to take 30 days to drill down to a depth of 2,300 metres.

24 Jun 2015

Wintershall spuds Zeppelin prospect

Lundin Petroleum AB (“Lundin”) has announced that the company’s subsidiary Lundin Norway AS (“Lundin Norway”) has begun drilling its second appraisal well on the Alta field in the Barents sea and has also commenced further appraisal drilling on the Edvard Greig field in the Norwegian North Sea. Meanwhile drilling has also begun on the partner-operated Zeppelin exploration well. The second .... [+ read more] Alta appraisal well (7220/11-3) was spud in PL 609 and is targeting the Permian reservoir. The planned depth of the well is 2,070 metres and the well is being drilled from the Island Innovator. The Edvard Greig appraisal well (16/1-23 S) is located in PL 338 and Lundin Norway plans to spud the well to a total depth of 2,200 metres. Drilling is expected to take around 60 days and is being performed by the Rowan Viking jackup rig. Meanwhile the Borgland Dolphin semisub rig recently spud the Zeppelin exploration well in PL 734. Wintershall is the operator of the well (10/4-1), and believes that Zeppelin holds prospective resources of 152 MMboe. The well is expected to take 30 days to drill down to a depth of 2,300 metres.

23 Jun 2015

Tullow hits dust with Zumba well

Tullow Oil plc (“Tullow”) has announced that the Zumba exploration well (6507/11-11) in licence area PL 591 in the Norwegian Sea has not encountered hydrocarbons and will now be plugged and abandoned. The primary objective of the well was to prove hydrocarbons in the Upper Jurassic Rogn Formation with a secondary target in the Mid-Jurassic Garn Formation of the Fangst Group. .... [+ read more] The well found no reservoir development in the Rogn Formation and, while the Garn Formation had good reservoir quality, no hydrocarbons were present in either target. The well was drilled by the Leiv Eiriksson semisub rig in 270 metres of water to a total depth of 2,875 metres. Tullow Oil Norge AS is the operator of PL 591 with 40% equity. Lime Petroleum Norway AS (25%), Rocksource (20%*) and North Energy ASA (15%) hold non-operated interests.

23 Jun 2015

Wintershall set to spud wildcat well in PL 734

The Norwegian Petroleum Directorate has granted Wintershall Norge AS a drilling permit for well 10/4-1. Well 10/4-1 will be drilled from the Borgland Dolphin drilling facility in position 57°40’20.08’’ north and 5°09’18.79’’ east. The drilling programme for well 10/4-1 relates to the drilling of a wildcat well in production licence 734. Wintershall Norge AS is the operator with a 40 .... [+ read more] per cent ownership interest. The other licensees are Centrica Resources (Norge) AS and Lundin Norway AS with 30 per cent each. Production licence 734 was awarded in APA 2013. The area in this production licence lies in the south-eastern part of the North Sea and consists of the eastern part of block 10/4. Well 10/4-1 is the first exploration well in this production licence. The permit is contingent upon the operator securing all other consents and permits required by other authorities prior to commencing the drilling activity.

23 Jun 2015

Transocean scraps two more floaters and delays more newbuilds

Transocean Ltd (“Transocean”) today issued its updated fleet summary report, with the company announcing its plan to retire a further two floating rigs from its operational fleet as well as delay the delivery of two newbuild drillships. Transocean has classified both the GSF Celtic Sea and Transocean Amirante units as being held for sale, with the GSF Celtic Sea being either .... [+ read more] sold for use in a non-drilling capacity or recycled, whilst the Transocean Amirante will be recycled. Transocean has been the most active scrapper of rigs thus far in 2015 and has indicated its intent to scrap a total of 20 floaters. Meanwhile the company also announced its plan to delay the delivery of its two newbuild drillships currently under construction at the Jurong Shipyard in Singapore. Transocean has delayed the delivery of each unit by 24 months, with delivery now expected in Q2 2019 and Q1 2020. This follows Transocean’s recent trend of delaying newbuild assets, the company recently delayed delivery of its five newbuild jackup rigs.

23 Jun 2015

VNG Norge AS spuds Boomerang prospect

VNG Norge has now started the operation of the first of two new explorations wells in PL586, the licence where the Pil & Bue discoveries were made in 2014. VNG Norge took over the rig Transocean Arctic late on Friday 19th June after the rig had completed the drilling operation at Crossbill prospect for the operator Wintershall. After having sailed 190 .... [+ read more] nautical miles from Crossbill in the North Sea, Transocean Arctic arrived on location in the Norwegian Sea Sunday 21st June. The rig was towed and escorted by the anchor handlers Boa Bison and Havila Mars, which together with Siem Opal, finished the anchor operations.The main well 6406/12-4 S, was spudded today Monday 22nd June at 11:45 p.m. After the main well, a sidetrack - 6406/12-4, is to be drilled. Expected duration of the drilling operation is between 85 and 135 days. The wells will be permanently plugged and abandoned before Transocean Artic is moved to a new location within the same licence for drilling a second exploration well in PL586.

22 Jun 2015

Haribo prospect spudded in Norway

Noreco Norway AS (“Noreco”) has announced that the drilling of the Haribo prospect in Norwegian licence PL616 has started. Noreco holds a 20% interest in the licence. The Haribo well (2/11-11) is being drilled by the Transocean Searcher semisub. The drilling period is expected to take approximately 45 days. The Haribo prospect is located 10 km south west of the Valhall .... [+ read more] Field in the Norwegian part of the North Sea. The predicted reservoir is chalk of Upper Cretaceous age in a depth of about 2900 meter. Noreco Norway estimates the prospect to contain 69 to 192 million barrels of oil gross on licence PL616 with a 42 per cent chance of success. These volume and risk estimates are in line with what Noreco has previously communicated to the market.

22 Jun 2015

'Ocean Guardian' contracted for offshore drilling in Ireland

Lansdowne Oil & Gas plc, a North Celtic Sea focussed oil and gas company, is pleased to announce that PSE Seven Heads Limited, the operator of SEL 4/07, and a wholly owned subsidiary of PSE Kinsale Energy Limited ("Kinsale Energy") has entered into a contract with Diamond Offshore Drilling (UK) Limited for the Ocean Guardian semisub to drill a well on .... [+ read more] the Midleton Prospect. The Ocean Guardian is expected to drill the Midleton well during August 2015, upon completion of its current contract with Shell. Kinsale Energy holds an 80% interest in SEL 4/07, with Lansdowne holding the remaining 20%. Through the farm-in agreement previously announced, Kinsale Energy will fund 100% of the costs of drilling a well (including the site survey work) on the Midleton prospect. Kinsale Energy is continuing work on well planning and further announcements will be made in due course.

19 Jun 2015

Lundin to plug former appraisal well with 'Maersk Guardian'

Lundin has received consent to use the Maersk Guardian jackup to permanently plug well 7/8-5 S. The work is expected to take around 18 days. Well 7/8-5 S was an appraisal well for the Krabbe discovery, it was drilled in April 2006, but it turned out to be a dry well. .... [+ read more]

19 Jun 2015

PSA performs audit of 'Maersk Gallant'

Between 16th and 20th March 2015, the Petroleum Safety Authority (“PSA”) carried out an audit of Statoil and Maersk Drilling concerning HPHT drilling operations at the 2/4-22 Romeo and 2/4-23 Julius exploration wells using the Maersk Gallant jackup. The objective of the audit was to verify Statoil and Maersk Drilling's planning, experience transfer and execution of high pressure, high temperature exploration .... [+ read more] drilling of the Romeo and Julius exploration wells. The results of the audit found that non-conformities were identified in connection with; working environment committee and working environment measures. The PSA has issued additional improvement points and have given Statoil and Maersk Drilling a dealing of the August 1st 2015 to report on how it plans to deal with the points raised.

18 Jun 2015

Wintershall drills duster in Norway

Wintershall Norge AS, operator of production licence 378, is in the process of completing the drilling of wildcat well 35/12-5 S. The well was drilled about 15 km southwest of the Gjøa field in the North Sea and 80 kilometres southwest of Florø. The purpose of the well was to prove petroleum in reservoir rocks from the Upper Jurassic (the .... [+ read more] Heather, Sognefjord and Fensfjord formations). Well 35/12-5 S encountered about 10 metres of sandstone in the Heather formation, 35 metres of sandstone in the Sognefjord formation and 32 metres of sandstone in the Fensfjord formation, all with good reservoir quality. It also encountered 9 metres of sandstone with poor reservoir quality in the Etive formation. The well is dry. Data acquisition and sampling have been carried out. This is the fifth exploration well in production licence 378. The licence was awarded in APA 2005. Well 35/12-5 S was drilled to a vertical depth of 3369 metres and a measured depth of 3570 metres below the sea surface and was terminated in the Oseberg formation in the Middle Jurassic. Water depth at the site is 353 metres. The well will now be permanently plugged and abandoned. Well 35/12-5 S was drilled by the Transocean Arctic drilling facility, which is now scheduled to drill wildcat well 6406/12-4 S in production licence 586 in the Norwegian Sea, operated by VNG Norge AS.

18 Jun 2015

Contract extended, but rate cut for 'Borgsten Dolphin'

Dolphin Drilling Ltd (“Dolphin”), a subsidiary of Fred. Olsen Energy ASA, has entered into a contract amendment for the provision of the Tender Support Vessel Borgsten Dolphin with Total E&P UK Ltd (“Total”). The amendment covers a revised contract period commencing 1st October 2015 and continuing to 31st January 2018, subject to certain early termination rights from end 2016. Contract terms .... [+ read more] prior to 1st October 2015 remain in accordance with the previously reported Total agreement. The estimated contract value for the revised period from 1st October 2015 to 31st January 2018 is approximately USD141 million. By amending the contract, Total have opted to cut the dayrate from USD202k/per day to around USD165k/per day.

17 Jun 2015

VNG Norge AS set to spud another exploration well on PL586

The Norwegian Petroleum Directorate (NPD) has granted VNG Norge AS a drilling permit for well 6406/12-4 S, cf. Section 8 of the Resource Management Regulations. Well 6406/12-4 S will be drilled from the Transocean Arctic drilling facility in position 64°1'7.47'' north and 6°46'31.28'' east after completing wildcat well 35/12-5 in production licence 378 for Wintershall Norge AS. The drilling programme .... [+ read more] for well 6406/12-4 S relates to the drilling of a wildcat well in production licence 586. VNG Norge AS is the operator with an ownership interest of 30 per cent. The other licensees are Spike Exploration Holding AS (30 per cent), Faroe Petroleum Norge AS (25 per cent) and Rocksource Exploration Norway AS (15 per cent). The area in this licence consists of part of block 6406/11 and part of block 6406/12. The well will be drilled about 33 kilometres southwest of the Njord field. Production licence 586 was awarded on 4 February 2011 (APA 2010). This is the fourth well to be drilled in the licence. The permit is contingent upon the operator having secured all other permits and consents required by other authorities before the drilling starts.

17 Jun 2015

Repsol secures permit for Hagar drilling

The Norwegian Petroleum Directorate (NPD) has granted Repsol Exploration Norge AS a drilling permit for well 6306/5-2, cf. Section 8 of the Resource Management Regulations. Well 6306/5-2 will be drilled from the Bredford Dolphin drilling facility in position 63°43'52.31'' north and 6°34'27.34'' east after completing wildcat well 16/4-9 S in production licence 359 for Lundin Norway AS. The drilling programme .... [+ read more] for well 6306/5-2 concerns the drilling of a wildcat well in production licence 642. Repsol Exploration Norge AS is the operator with an ownership interest of 40 per cent. The other licensees are OMV Norge AS (20 per cent), Petoro AS (20 per cent) and Tullow Oil Norge AS (20 per cent). The area in this licence consists of part of block 6306/2 and part of block 6306/5. The well will be drilled about 64 kilometres northeast of the Ormen Lange field and about 34 kilometres south of the 6406/12-3 S (Pil) discovery. Production licence 642 was awarded on 3 February 2012 (APA 2011). This is the first well to be drilled in the licence. The permit is contingent upon the operator having secured all other permits and consents required by other authorities before the drilling starts.

17 Jun 2015

Lundin spuds Luno II North prospect

Lundin Petroleum AB (“Lundin Petroleum”) is pleased to announce that its wholly owned subsidiary Lundin Norway AS (“Lundin Norway”) has commenced drilling of exploration well 16/4-9 S on the Luno II North prospect. The Luno II discovery is located approximately 15 km south of the Edvard Grieg field in the North Sea sector of the Norwegian Continental Shelf. The well is .... [+ read more] located in PL359 and will explore the Luno II North segment, located directly northwest of the Luno II discovery. The main objective of well 16/4-9 S is to test the hydrocarbon potential and reservoir properties in the Luno II North prospect. The reservoir is expected to be of Jurassic/Triassic age. Lundin Petroleum estimates the Luno II North prospect to contain gross unrisked prospective resources of 24 million barrels of oil equivalents (“MMboe”). This prospect is adjacent to the Luno II discovery which has an estimated contingent resource range of 27 to 71 MMboe. The planned total depth is approximately 2,490 metres below mean sea level and the well will be drilled with the semi-submersible drilling unit Bredford Dolphin. The drilling operation is expected to take approximately 50 days. Lundin Norway is the operator of PL359 with 50% working interest. The partners are OMV (Norge) AS with 20%, Wintershall Norge AS with 15% and Statoil Petroleum AS with 15% working interest.

17 Jun 2015

Seadrill sells 'West Polaris' to Seadrill Partners LLC

Seadrill Limited ("Seadrill") announced today that it has entered into an agreement with Seadrill Operating LP ("Seadrill Operating"), the 58% owned subsidiary of Seadrill Partners LLC ("Seadrill Partners"), pursuant to which Seadrill Operating will acquire all of the shares of Seadrill Polaris Ltd. ("Seadrill Polaris"), the entity that owns and operates the drillship, the West Polaris (the "Polaris Acquisition") from Seadrill. .... [+ read more] The Polaris Acquisition is expected to close within 7 days. The West Polaris is a 6th generation, dynamically positioned drillship delivered from the Samsung shipyard in 2008. The West Polaris is expected to carry out operations in Angola until the end of its contract with ExxonMobil in March 2018. The total consideration for the Polaris Acquisition is comprised of USD204 million in cash and USD336 million of debt outstanding under the existing facility financing the West Polaris. Seadrill Operating will fund the balance of the purchase price with a seller's credit of USD50 million due in 2021 that carries an interest rate of 6.5% per annum. Based on the assumed present value of the seller's credit, excess dayrate to be paid to the Company under the current drilling contract and assumed excess dayrate to be paid to the Company following the conclusion of the current drilling contract, the board of directors of the Company believes that the total value proposition of the Polaris Acquisition for Seadrill is approximately USD750 million. The West Polaris is currently contracted with ExxonMobil on a daily rate of USD653,000. Under the terms of the acquisition agreement, Seadrill Polaris has agreed to pay Seadrill any dayrate it receives in excess of USD450,000 per day, adjusted for daily utilization, for the remainder of the ExxonMobil contract. Assuming an average economic utilization of 95%, Seadrill will receive approximately USD60 million in cash per year from the current ExxonMobil contract. Additionally, Seadrill Polaris has agreed to pay Seadrill 50% of any dayrate above USD450,000 per day, adjusted for daily utilization, after the conclusion of the existing contract until 2025. As part of the acquisition agreement, Seadrill Operating's obligation to repay the USD50 million seller's credit due to Seadrill will be reduced if the average contracted dayrate under any replacement contract is below USD450,000 until the seller's credit's maturity in 2021. The amount of seller's credit due will be reduced until Seadrill Partners' effective dayrate is USD450,000 or until the seller's credit is reduced to zero. Should the average dayrate of the replacement contract be above USD450,000, the entire USD50 million seller's credit must be paid to Seadrill upon maturity of the seller's credit in 2021. By agreeing to sell the West Polaris to Seadrill Partners, Seadrill is able to realize USD204 million in cash upon closing of the transaction while retaining up to USD203,000 per day in revenues under the current drilling contract without the associated operating expense. Additionally, following the conclusion of the current contract, Seadrill will continue to have a degree of exposure to future dayrates by sharing revenues above USD450,000 per day with Seadrill Partners, again without the associated operating expense. The Board is pleased to announce a transaction that serves to realize value from multiple sources in addition to the sale price, while at the same time supporting an important associated company in its goals to increase distribution coverage, asset diversification and revenue backlog.

16 Jun 2015

PSA approves 'Maersk Integrator' for Gina Krog drilling

Statoil has received consent to use the Maersk Integrator jackup for production drilling and completion of fourteen wells at the Gina Krog field in Norway. Gina Krog is an oil and gas discovery situated around 250 kilometres west of Stavanger and 30 kilometres north-west of the Sleipner A facility. Water depth at the site is approximately 110 metres. The development concept .... [+ read more] is a new steel platform and an oil storage vessel with a capacity of 850,000 barrels. The field was proven in 1974. The reservoir contains oil and gas in Middle Jurassic sandstone in the Hugin formation. Statoil has now received consent from the PSA to use Maersk Integrator to drill and complete new production wells on the field.

16 Jun 2015

PSA approves use of 'Maersk Gallant' for P&A at Eldfisk

The PSA has granted ConocoPhillips consent to use the Maersk Gallant jackup drilling rig for plugging and abandoning a production well at Eldfisk 2/7 A. Eldfisk is an oil field lying due south of Ekofisk in 70-75 metres of water in the southern North Sea. Production began in 1979. Mærsk Gallant is a jack-up drilling facility, built at Far East Levingston .... [+ read more] Shipbuilding (FELS) in Singapore in 1993. The facility is operated by Maersk Contractors Norge A/S. It received Acknowledgement of Compliance (AoC) in August 2002. The Petroleum Safety Authority (“PSA”) Norway has now granted consent to use Maersk Gallant at Eldfisk in accordance with ConocoPhillips's application.

15 Jun 2015

Statoil contracts Odfjell Drilling for Johan Sverdrup development

Odfjell Drilling Ltd. (“Odfjell”) has announced that the company has been awarded two contracts related to the drilling services for the Johan Sverdrup field in Norway. The first contract is a three year contract for the Deepsea Atlantic semisub which is scheduled to begin in March 2016. The firm contract period is for three years with a value of USD330 million .... [+ read more] and comes with 6x6 potential option periods. The second contract is related to the operation of platform drilling services on-board the Johan Sverdrup drilling platform and this contract is over a four year period.

15 Jun 2015

Noble Energy spuds Humpback well

Falkland Oil and Gas Limited (“FOGL”), the oil and gas exploration company focused on its extensive licence areas to the North, South and East of the Falklands islands, is pleased to announce that the 'Humpback' exploration well, (the "Well") was spudded on 13th June 2015. The well is located on licence PL012 in which FOGL has a 52.5% working interest .... [+ read more] and will target the Humpback prospect. Humpback is located within a cluster of similar prospects, in the Fitzroy sub-basin, which have a total, combined, prospective resource of over one billion barrels of oil. The well will test multiple stacked reservoirs within the Cretaceous Diomedea fan complex. The Humpback well is located in a water depth of approximately 1,260 metres and is expected to reach a total depth of 5,350 metres. The well is anticipated to take approximately 65 days to drill. A further release will be issued once logging is completed. FOGL is partially carried through the costs of this well by Noble Energy (Licence Operator) and has a paying interest of 27.5%.

12 Jun 2015

Lundin completes Alta appraisal drilling

Lundin Petroleum AB (“Lundin Petroleum”) is pleased to announce that its wholly owned subsidiary Lundin Norway AS (“Lundin Norway”) has successfully completed the drilling of appraisal well 7220/11-2 and sidetrack 7220/11-2 A in the western part of the Alta discovery in PL609. The Alta discovery is located 10 to 20 km northeast of Lundin Petroleum’s Gohta discovery in the Barents Sea .... [+ read more] South and approximately 160 km from the Norwegian coastline. The Alta discovery well 7220/11-1 was completed in October 2014. The preliminary evaluation of the gross recoverable oil and gas resource range from the Alta discovery well after the first well was estimated at 125 to 400 million barrels of oil equivalents. The appraisal well 7220/11-2 was located approximately 6.5 km southwest of the original Alta discovery well 7220/11-1. The main objectives were successfully achieved which were to confirm the reservoir model and prove the presence of hydrocarbon columns and fluid contacts similar to those established in the Alta discovery well. The well encountered a 50 metres thick gas column in rocks of varying reservoir quality. A sidetrack, 7220/11-2 A, was drilled 330 metres west of well 7220/11-2. The sidetrack encountered movable oil. The pressure data and fluid properties indicate communication between both the appraisal wells and the discovery well 7220/11-1. Extensive data acquisition and sampling were performed in both wells, including conventional coring and fluid sampling. One production test (DST) was carried out in 7220/11-2 A. The maximum production rate was 860 barrels of oil per day and 0.65 million cubic feet of gas per day through a 24/64” choke. The pressure build-up during the test showed increased permeability thickness away from the well bore, interpreted to be in a westerly direction based on seismic data. Ashley Heppenstall, President and CEO of Lundin Petroleum, comments; "The appraisal wells on the western flank of Alta have confirmed our geological model and the existence of hydrocarbons at this location. Whilst the reservoir encountered is of variable quality, the production test and data acquired provides us with confidence of connectivity across the structure and improved reservoir quality away from the well bore". 7220/11-2 and 7220/11-2 A are the second and third wells drilled in PL609. The license was awarded in the 21st Licencing Round in 2011. The wells were drilled to total vertical depths of 2,020 and 2,041 metres below mean sea level, respectively. The water depth was 379 metres. The wells were drilled using the drilling rig Island Innovator and are now being permanently plugged and abandoned. The Island Innovator will then proceed to drill the next appraisal well, 7220/11-3, on the eastern flank of the Alta discovery in PL609. The well is expected to spud mid-June. Lundin Norway is operator and holds 40 percent working interest in PL609. The partners are DEA Norge AS and Idemitsu Petroleum Norge AS with 30 percent working interest each.

10 Jun 2015

Lundin given approval to drill Edvard Greig SE appraisal well

The Norwegian Petroleum Directorate has granted Lundin Norway AS a drilling permit for well 16/1-23 S, cf. Section 8 of the Resource Management Regulations. Well 16/1-23 S will be drilled from the Rowan Viking drilling facility at position 58°49’47.04’’ north 02°16’56.00’’ east in production licence 338. The drilling programme for well 16/1-23 S relates to the drilling of an appraisal .... [+ read more] well in production licence 338. Lundin is the operator with a 50 per cent ownership interest. The other licensees are OMV (Norge) AS with 20 per cent, Statoil Petroleum AS and Wintershall Norge AS, each with 15 per cent. The area in this licence consists of parts of block 16/1. The well will be drilled to the southeast of the Edvard Grieg field in the central part of the North Sea. Production licence 338 was awarded on 17 December 2004 (APA 2004). This is the tenth exploration well to be drilled within the area of this licence. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing the drilling activity.

9 Jun 2015

Statoil makes minor gas discovery at Gymir prospect

Statoil Petroleum AS, operator of production licence 602, has concluded the drilling of wildcat well 6706/11-2. The well encountered gas. The well was drilled about 20 kilometres west of the Aasta Hansteen field in the northern part of the Norwegian Sea. The objective of the well was to prove petroleum in Upper Cretaceous reservoir rocks (the Nise formation). The .... [+ read more] well encountered a total gas column of about 70 metres in the Nise formation, of which 40 metres in sandstone with very good reservoir quality. Preliminary estimates place the size of the discovery between one and three billion standard cubic metres (Sm3 ) of recoverable gas. The well was not formation-tested, but extensive data acquisition and sampling have been carried out. The licensees will assess the discovery together with other discoveries in this production licence and the neighbouring licence (218) with regard to development and tie-in to the Aasta Hansteen field. This is the second exploration well in production licence 602. The licence was awarded in the 21st licensing round in 2011. Well 6706/11-2 was drilled to a vertical depth of 2556 metres below the sea surface, and was terminated in the Nise formation in the Upper Cretaceous. Water depth at the site is 1272 metres. The well will now be permanently plugged and abandoned. Well 6706/11-2 was drilled by the Transocean Spitsbergen drilling facility, which will now be laid up at Averøy outside Kristiansund. The rig has completed its Contract with Statoil.

9 Jun 2015

Suncor spuds Niobe prospect in the UK

Trapoil (“TRAP”), an independent oil and gas exploration, appraisal and production company focused on the UK Continental Shelf ("UKCS") region of the North Sea, has announced that operations have commenced on the Niobe (Licence P.1889, Blocks 12/26b & 27) exploration prospect ("Niobe"). The well is being drilled using the ENSCO 100 jack up rig and well operations are currently anticipated to .... [+ read more] last approximately 31 days in the dry hole case. The ENSCO 100 rig left Dundee shipyard on 4th June 2015 and was under tight tow to the Niobe prospect location until the 8th June 2015. The ENSCO 100 successfully spudded the well on the 9th June 2015. Water depth at the drilling location is 181 feet. The partners in Licence P.1889 are Suncor Energy UK Limited, operator (49.5 per cent. equity interest), Norwegian Energy Company UK Limited (22.5 per cent. equity interest) and Trap Oil Limited (28 per cent. equity interest, of which 2.5 per cent. is a carried interest).

9 Jun 2015

CIMC strikes steel on 'Beacon Pacific'

On 9th June 2015, the semisubmersible drilling rig, Beacon Pacific, built by CIMC Raffles for Beacon Pacific Group Ltd., cut its first steel in CIMC Raffles Yantai Shipyard. Based on GM4-D design and former four delivered GM series semisubmersible drilling rigs experience, CIMC Raffles is cooperated with Global Maritime on the basic design and owns 80% intellectual property right. .... [+ read more] Beacon Pacific can be operated in the harsh-environmental areas like Norwegian North Sea and the Barents Sea with working depth up to 500m, drilling depth up to 8,000m, working temperature to -20? and DP3 dynamic positioning system and 8-point mooring system. It is satisfied with NORSOK standards and DNV GL latest specifications.

8 Jun 2015

Panoro announces contracting of 'Scarabeo 3'

Panoro Energy ASA (”Panoro”), an independent oil and gas E&P company focused on West Africa, has provided the following operations update. Yinka Folawiyo Petroleum (“YFP”) the operator of the OML113 license has, on behalf of the joint venture partners, entered into a rig contract with Saipem for the Scarabeo 3 drilling rig to carry out the drilling and completion programme for .... [+ read more] the Aje Field Cenomanian oil development. Aje is an offshore field located in the western part of Nigeria in the Dahomey Basin at the border with Benin, with first oil targeted for December 2015. The field is situated in water depths ranging from 100 to 1,000 meters about 24 km from the coast. Panoro Energy holds a 6.502% participating interest in OML113 (with a 12.1913% revenue interest and 16.255% paying interest in the Aje Field). The Aje Field contains hydrocarbon resources in sandstone reservoirs in three main levels - a Turonian gas condensate reservoir, a Cenomanian oil reservoir and an Albian gas condensate reservoir. The Scarabeo 3 rig is a semi-submersible rig currently stationed offshore Lagos. The rig will be moved 18 nautical miles to the Aje drilling location and will be used to carry out well operations for the first phase of the Aje Cenomanian Oil field development that includes two subsea production wells. The well operations will comprise the completion of the existing Aje-4 well as a production well, and the drilling and completion of a new well, Aje-5, which will be drilled to the Aje-2 subsurface location. The Aje-2 well demonstrated high reservoir productivity in a Cenomanian production test conducted in 1997, flowing approximately 3,700 bopd of 41°API oil under suboptimal well conditions. Well operations are expected to commence in early Q3-2015 and are likely to take approximately 90 days to complete. Once well operations have been completed, subsea equipment will be installed and the wells will be tied back to the Front Puffin FPSO, currently undergoing refurbishment in Singapore.

8 Jun 2015

PSA gives AOC to 'Maersk Integrator'

Maersk Drilling has received the PSA's Acknowledgement of Compliance (“AoC”) for the Maersk Integrator jack-up drilling facility. Maersk Integrator is a jack-up drilling facility, delivered by the Keppel Shipyard in Singapore in 2014. The facility will be operated by Maersk Drilling Norge AS. In total, 57 mobile facilities have received an Acknowledgement of Compliance from the PSA. It is the PSA's .... [+ read more] assessment that petroleum activities may be carried out using the Maersk Integrator facility within the regulatory framework. The validity of the Acknowledgement of Compliance assumes that Maersk Drilling Norge AS ensures that the facility and relevant parts of the company’s organisation and management systems are maintained, to fulfil the terms and conditions set out in the PSA’s decision.

4 Jun 2015

Lundin makes non-commercial discovery at Morkel prospect

Lundin Norway AS, operator of production licence 579, is in the process of concluding the drilling of wildcat well 33/2-2 S. The well was drilled about 40 kilometres northwest of the Snorre field in the North Sea, and 180 kilometres west of Florø. The primary exploration target for the well was to prove petroleum in Upper and Middle Jurassic reservoir .... [+ read more] rocks (the Draupne formation and the Brent Group). The secondary exploration target was to prove hydrocarbons in Lower Jurassic (Statfjord Group) and Triassic reservoir rocks (the Lunde formation). The well encountered oil over an interval of about 173 metres in what was presumably the Triassic Lunde formation, with heterolithic sandstones with poor reservoir quality. No recoverable resources have been estimated at this point. A formation test was conducted. The production rate was 68 Sm3 oil per flow day through a 24/64-inch nozzle opening. Extensive data acquisition and sampling were also carried out. The licensees in production licence 579 will assess the discovery with a view toward further follow-up. This is the first exploration well in production licence 579, which was awarded in APA 2010. Well 33/2-2 S was drilled to a vertical depth of 3498 metres below the sea surface and was terminated in sandstone and shale, presumably belonging to the Alke formation in the Triassic. Water depth at the site is 340 metres. The well will now be permanently plugged and abandoned. Well 33/2-2 S was drilled by the Bredford Dolphin drilling facility, which will now drill wildcat well 16/4-9 S in production licence 359 in the North Sea, where Lundin Norway AS is the operator.

4 Jun 2015

Paraon Offshore announces sale and leaseback agreement for prospector jackups

Paragon Offshore plc ("Paragon") today announced that certain wholly owned subsidiaries of the company, which were part of the company's acquisition of Prospector Offshore Drilling S.A. ("Prospector"), have entered into a combined USD300 million sale-leaseback financing facility with subsidiaries of SinoEnergy, a private investment firm registered in the British Virgin Islands. Net of fees and expenses, Prospector expects to receive net .... [+ read more] proceeds of approximately $292 million. Under the terms of the agreement, Prospector will sell two heavy-duty, harsh-environment jackup units, Prospector 1 and Prospector 5, to subsidiaries of SinoEnergy and immediately enter into a bareboat rental charter for the assets for a period of five years. The bareboat charter fee for Prospector 1, which is under firm contract until mid-September 2016, is USD71,000 per day through November 2016, after which it will be USD42,000 per day for the remainder of the charter. The bareboat charter fee for Prospector 5, which is under firm contract until mid-November 2017, is USD71,000 per day through February 2018, after which it will also be reduced to USD42,000 per day. The combined implied cost of borrowing is approximately 7.5%, including fees and expenses. The lease financing is non-recourse to Paragon. "We are extremely pleased to have secured this financing on the two Prospector rigs at what we consider to be an attractive rate in this environment," said Randall D. Stilley, President and Chief Executive Officer of Paragon. "As a result of this financing initiative, we have increased financial flexibility and are evaluating options for the use of the proceeds, whether it be to retain the cash in order to increase our liquidity or to further strengthen the balance sheet through debt reduction." The facilities are expected to fund by early third quarter 2015. Funding is subject to customary conditions for a transaction of this nature

1 Jun 2015

Hercules agrees to rate reductions and Saudi Aramco cancels termination notice for 'Hercules 261'

Hercules Offshore, Inc. (“Hercules”) announced today it had received a notice from Saudi Aramco withdrawing its previously issued termination notice for the Hercules 261 jackup. Following the withdrawal of this termination notice, the Hercules 261 is now fully contracted up until September 2019. Meanwhile Hercules also announced that it has agreed to rate reductions for its three jackups currently contracted to .... [+ read more] Saudi Aramco; Hercules 261, Hercules 262 and Hercules 266. The rates for all three units will be reduced to USD67,000 and apply from the 1st January 2015. The rate reductions for the Hercules 261 and 262 run until 31st December 2016, whilst the Hercules 266 reduction will be applied for the remainder of the units contract which completes in November 2015.

1 Jun 2015

'Atwood Achiever' spuds MZ-1 well in Morocco

Pura Vida Energy NL (“Pura Vida”) has announced that the Atwood Achiever drillship has successfully spudded the MZ-1 well within the Mazagan permit, offshore Morocco. Freeport-McMoran oil & gas is the operator of the permit. Drilling is expected to take around 2-3 months. The MZ-1 well is targeting the Ouanoukrim prospect which is a series of five stacked targets in both .... [+ read more] the cretaceous and Jurassic reservoirs. The unit recently completed the Tortue-1 well for Kosmos Energy in Mauritania.

29 May 2015

Statoil given approval to drill two exploration wells in PL 029B

The Norwegian Petroleum Directorate has granted Statoil Petroleum AS a drilling permit for wells 15/6-13 A and B, cf. Section 8 of the Resource Management Regulations. Wells 15/6-13 A and B will be drilled from the Songa Trym drilling facility at position 58°36’55.48” north and 01°45’40.58” east near the Gina Krog field in the central part of the North Sea. .... [+ read more] The drilling programme for well 15/6-13 A and B relates to the drilling of a wildcat well in production licence 029 B. Statoil Petroleum AS is the operator with an ownership interest of 50 per cent. The other licensees are Total E&P Norge AS and Det norske oljeselskap ASA with 30 and 20 per cent each, respectively. The area in this licence consists of a part of block 15/6. Production licence 029 B was awarded on 11 May 2001 after being carved out of 029, which was awarded in the 2nd licensing round in 1969. These are the third and fourth exploration wells to be drilled in the licence, but wildcat wells have been drilled before within the area this licence covers. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

28 May 2015

Premier announces discovery at Isobel Deep

Premier Oil is pleased to announce an oil discovery at the Isobel Deep exploration well 14/20-1 in the North Falkland Basin, approximately 30km south of the Sea Lion field. The Isobel Deep exploration well has been drilled to a depth of 8,289 feet reaching top reservoir on prognosis. The bottom 75 feet of the well consists of oil bearing F3 sands. .... [+ read more] These sands were at a higher than expected reservoir pressure and this resulted in an influx into the well. As part of the operations to remove the influx, oil was recovered from the well and appears similar in nature to Sea Lion crude. As a result of the new geological information it has been decided to suspend operations on the well and release the rig to drill in the South Falkland Basin. The rig is expected to return to continue operations in the North Falklands Basin in August. Premier is now considering the optimal appraisal programme for the Elaine/Isobel complex in PL004.

28 May 2015

Det Norske set to drill new appraisal at Ivar Aasen field

The Norwegian Petroleum Directorate has granted Det norske oljeselskap AS a drilling permit for well 16/1-22 A, cf. Section 8 of the Resource Management Regulations. Well 16/1-22 A will be drilled from the Maersk Interceptor drilling facility in position 58°54’23.1’’ north and 02°09’43.2’’ east in production licence 001 B, after completing drilling of appraisal well 16/1-22 S. The drilling programme .... [+ read more] for well 16/1-22 A relates to the drilling of an appraisal well on the Ivar Aasen field, where Det norske is the operator with an ownership interest of 34.7862 per cent. The other licensees are Statoil Petroleum AS (41.4730 per cent), Bayerngas Norge AS (12.3173 per cent), Wintershall Norge AS (6.4615 per cent), VNG Norge AS (3.0230 per cent), Lundin Norway AS (1.3850 per cent) and OMV (Norge) AS (0.5540 per cent). The area in this licence is part of block 16/1. The well will be drilled in the south-western part of the Ivar Aasen field in the central part of the North Sea. Production licence 001 B was carved out on 1 September 1999 from production licence 001, which was awarded on 1 September 1965 (Licensing Round 1-A). This is the eighth exploration well to be drilled within the licence area, and the tenth on the Ivar Aasen field. The permit is conditional upon the operator securing all other permits and consents required by other authorities prior to commencing the drilling activity.

28 May 2015

Statoil given drilling approval from NPD

The Norwegian Petroleum Directorate has granted Statoil Petroleum AS a drilling permit for wells 15/6-13 A and B, cf. Section 8 of the Resource Management Regulations. .... [+ read more]

26 May 2015

PSA approves Statoil's exploration plan for well 6706/11-2

Statoil has received consent to drill exploration well 6706/11-2 in the Norwegian Sea. Statoil is the operator for production licence 602 in block 6706/11 in the Norwegian Sea. The field is located around 233 kilometres from the nearest mainland at Skomvær in the county of Nordland. Drilling is scheduled to begin in June 2015 and estimated to last 28 days, depending .... [+ read more] on whether a discovery is made. Drilling will be performed using Transocean Spitsbergen, which is a semi-submersible mobile drilling facility of the Aker H-6e type. The facility was completed in 2009 at the Aker Solutions yard in Stord; it is registered in the Marshall Islands and classified by DNV GL.

26 May 2015

Edison set to spud new exploration well on PL 616

The Norwegian Petroleum Directorate has issued a drilling permit for wellbore 2/11-11 to Edison Norge AS. Wellbore 2/11-11 will be drilled from the Transocean Searcher drilling facility at position 56°12’11.75’’N and 03°23’26.53”E. The drilling program for wellbore 2/11-11 applies to drilling of a wildcat well in production licence 616. Edison Energy Norge AS is the operator with an ownership interest .... [+ read more] of 25 per cent. The licensees are Noreco Norway AS with 20%, Concedo ASA with 20%, Skagen 44 AS with 15%, North Energy ASA with 15% and Lime Petroleum Norway AS with 5%. Production licence 616 was awarded in 2012 (APA 2011). The area in this production licence is located in the southernmost part of the North Sea and consists of parts of boundary blocks 2/7, 10 and 11. The well will be drilled about 8 km south of the Valhall field. This is the first well to be drilled in the licence. The drilling permit is granted on the condition that all other permits and consents required by other authorities have been secured before the drilling activity commences.

22 May 2015

Statoil's Bister prospect disappoints

Statoil Petroleum AS, operator of production licence 348 C, is in the process of completing the drilling of wildcat wells 6407/8-7 and 6407/8-7 A. Both wells have been drilled about four kilometres north of the Hyme field in the southern part of the Norwegian Sea and 140 kilometres north of Kristiansund. The primary exploration target in well 6407/8-7 was to .... [+ read more] prove petroleum in Middle Jurassic reservoir rocks (the Ile formation). The secondary exploration target was to prove petroleum in Lower Jurassic reservoir rocks (the Tilje and Åre formations). The well encountered about 95 metres of the Ile formation, of which 70 metres were sandstone with good reservoir properties. The Tilje and Åre formations were also encountered, in thicknesses of 200 and 170 metres respectively, of which 160 and 75 metres respectively are sandstone with good reservoir quality. The well is dry. The purpose of well 6407/8-7 A was to prove petroleum in Middle Jurassic reservoir rocks (the Tilje formation) higher up in the structure. The well encountered about 110 metres of reservoir rocks in the Tilje formation, of which 80 metres were sandstone of good reservoir quality. The well also encountered 200 metres of the Åre formation, of which 95 metres were sandstone with good reservoir properties. The well is classified as dry. Data collection has been carried out in both wells. These are the first and second exploration wells in production licence 348 C. Wells 6407/8-7 and 6407/8-7 A were drilled to measured depths of 3030 and 3178 metres, respectively, and vertical depths of 3030 and 2810 metres below the sea surface. Both were terminated in the Åre formation in the Lower Jurassic. Water depth at the site is 259 metres. The wells will now be permanently plugged and abandoned. The wells were drilled by the Transocean Spitsbergen drilling facility, which will now move on to drill wildcat well 6706/11-2 in the Norwegian Sea in production licence 602, where Statoil is the operator.

22 May 2015

Statoil lines up drilling of Gymir prospect

The Norwegian Petroleum Directorate (NPD) has granted Statoil Petroleum AS a drilling permit for well 6706/11-2, cf. Section 8 of the Resource Management Regulations. Well 6706/11-2 will be drilled from the Transocean Spitsbergen drilling facility in position 67°03’56.97”north and 06°32’57.45”east after completing the drilling of wildcat wells 6407/8-7 and 6407/8-7 A for Statoil in production licence 348 C. The drilling .... [+ read more] program for well 6706/11-2 relates to the drilling of wildcat wells in production licence 602. Statoil Petroleum AS is the operator with an ownership interest of 30 per cent. The other licensees are Centrica Resources AS (20 per cent), Petoro AS (20 per cent), Rocksources Exploration Norway AS (10 per cent), Wintershall Norge AS (10 per cent) and Atlantic Petroleum Norge (10 per cent). The area in this licence consists of part of block 6706/10, block 6706/11 and part of block 6706/12. The well will be drilled about 22 kilometres west of Aasta Hansteen (the Haklang field). Production licence 602 was awarded on 13 May 2011 in the 21st licensing round on the Norwegian shelf. This is the second well to be drilled in the licence. The permit is conditional upon the operator securing all other permits and consents required by other authorities prior to commencing the drilling activity.

21 May 2015

Suncor set to spud new exploration well in Norway

The Norwegian Petroleum Directorate (NPD) has granted Suncor Energy Norge AS a drilling permit for well 25/10-13 S, cf. Section 8 of the Resource Management Regulations. Well 25/10-13 S will be drilled from the Borgland Dolphin drilling facility in position 59°09’42.52’’ north 02°14’23.70’’ east in the central North Sea. The drilling programme for well 25/10-13 concerns the drilling of a .... [+ read more] wildcat well in production licence 571. Suncor Energy Norge AS is the operator with an ownership interest of 60 per cent. The others licensee is Statoil Petroleum AS with 40 per cent. The area in this licence consists of parts of blocks 25/7 and 25/10. Production licence 571 was awarded on 4 February 2011 (APA 2010). This is the first exploration well to be drilled in the licence, but exploration wells have previously been drilled within the area covered by this licence. The permit is contingent upon the operator having secured all other permits and consents required by other authorities before the drilling starts.

21 May 2015

Exxon announces discovery in Guyana

Exxon Mobil Corporation (“Exxon”) today announced a significant oil discovery at the Liza-1 well on the Stabroek Block, located approximately 120 miles offshore Guyana. The well was drilled by ExxonMobil’s affiliate, Esso Exploration and Production Guyana Ltd and encountered more than 295 feet (90 meters) of high-quality oil-bearing sandstone reservoirs. It was safely drilled to 17,825 feet (5,433 meters) in 5,719 .... [+ read more] feet (1,743 meters) of water. The Stabroek Block covers 6.6 million acres (26,800 square kilometers). “I am encouraged by the results of the first well on the Stabroek Block,” said Stephen M. Greenlee, president of ExxonMobil Exploration Company. “Over the coming months we will work to determine the commercial viability of the discovered resource, as well as evaluate other resource potential on the block.” The well was spud on March 5th, 2015. The well data will be analysed in the coming months to better determine the full resource potential. Esso Exploration and Production Guyana Ltd. holds 45% interest. Hess Guyana Exploration Limited holds 30% interest and CNOOC Nexen Petroleum Guyana Limited holds 25% interest.

20 May 2015

Talisman announces dry well at Snømus prospect

Talisman Energy Norge AS, operator of production licence 672, has concluded the drilling of wildcat well 15/12-24 S. The well was drilled in the central part of the North Sea about six kilometres north of the Varg field and 220 kilometres southwest of Stavanger. The purpose of the well was to prove petroleum in Upper Jurassic reservoir rocks (the Ula .... [+ read more] and Sandnes formations) and in Middle Jurassic reservoir rocks (the Hugin and Sleipner formations). The well encountered about 195 metres of sandstone mixed with siltstone in the Ula formation, of which 155 metres are sandstone of good to very good reservoir quality. The well also encountered 85 metres of sandstone mixed with siltstone in the Skagerrak formation in Upper Triassic, of which 45 metres are sandstone of generally poor reservoir quality. The well has weak traces of petroleum in sandstone rocks in both the Ula and Skagerrak formations. The well is classified as dry. Data acquisition and sampling have been carried out. This is the first exploration well in production licence 672. The licence was awarded in APA 2012. The well was drilled to vertical and measured depths of 3136 and 3141 metres below sea level, respectively, and was terminated in the Skagerrak formation in the Upper Triassic. Water depth at the site is 86 metres. The well has been permanently plugged and abandoned. Well 15/12-24 S was drilled by the Maersk Giant drilling facility, which will now start permanent plugging of wells on the Varg field in production licence 038 in the North Sea, where Talisman Energy Norge AS is the operator.

20 May 2015

Hercules announces sale of cold stacked jackups

Hercules Offshore, Inc. (“Hercules”) today released an updated version of its monthly fleet report and announced the sale of four jackup rigs. The jackup focused rig owner announced the sale of the previously cold stacked; Hercules 85, Hercules 153, Hercules 203 and Hercules 206. The four jackups were all previously cold stacked in 2009 and are either mat cantilever or leg .... [+ read more] slot units. The announcement of the sale is good news for the jackup market as the units are expected to have been retired from operational service. Rig owners have thus far preferred to stack their jackups during the current drilling downturn.

20 May 2015

PSA approves drilling of two production wells at Gullfaks Sør

Statoil has received consent from the Petroleum Safery Authority (“PSA”) in Norway to use the Deepsea Atlantic to drill two production wells at Gullfaks Sør. Statoil is the operator for Gullfaks Sør, located in the Tampen area in the northern part of the North Sea, south of the Gullfaks field. Gullfaks Sør has been developed using subsea well templates tied back .... [+ read more] to Gullfaks A and C by underwater pipelines. Production from the field began in 1998. Statoil intends to drill two production wells from a new well template on the Rimfaksdalen gas discovery. In addition, a well is to be drilled next to the well template to investigate if there is shallow gas nearby. This well will be plugged when the result is in. Water depth at the site is 137 metres.

20 May 2015

Rowan announces dayrate reduction and extended term for 'Rowan Gorilla V'

Offshore rig owner Rowan Companies plc (“Rowan”) announced the successful signing of one new contract along with a number of contract extensions. Rowan secured a one-year extension for its Rowan Gorilla V jackup with Total in the UK. The new one year term is accompanied by news that Total and Rowan have agreed to a rate reduction for the unit from .... [+ read more] USD274k to USD170k covering the period from 1st January 2015 until 31st December 2015. Following this period, the rate will rise to USD175k for the remainder of the contract term in 2016. Elsewhere, the Rowan EXL III jackup was awarded a one-well, 40-day contract with ExxonMobil in the US GoM at a dayrate of USD75k and the Rowan Stavanger and Ralph Coffman units were both awarded 30-day extensions to their existing contracts in the UK and Tunisia.

20 May 2015

Eni makes Libya gas discovery

Libya’s National Oil Corporation (“NOC”) today announced that operator Eni North Africa Libya (“Eni”) made an gas and condensate discovery in contract area D (NC41). Eni spudded the A1-01/01 well in January 2015 in the Sabratah Basin and is believed to have used the Transocean Amirante semisub to drill the well. The well is located approximately 140 km from the Libyan .... [+ read more] coast and 20 km North of Bouri Field, at an average water depth of about 125 m.

19 May 2015

Potential oil shows at Isobel Deep

Rockhopper Exploration plc (“Rockhopper”), the oil and gas exploration and production company with interests in the North Falkland Basin and the Greater Mediterranean region, is pleased to provide the following update ahead of the Company's AGM today in relation to the Isobel Deep Well. Following the penetration of a sand interval with suspected elevated formation pressure and oil shows, the operator .... [+ read more] (Premier Oil) has decided to set a cement plug over this interval and run the contingent 9 5/8" casing string in the shale section above, prior to drilling through the prognosed Isobel reservoir interval to the well TD (“Total Depth”). The contingent casing string will enable additional flexibility while drilling and evaluating the target formation. This scenario had been anticipated and the additional 9 5/8" casing is already on the rig. The presence of oil shows is not necessarily indicative of net pay and conclusive results for the well will not be available until drilling operations have been completed and logging data collected. A further announcement on the results of the well will now be likely in early June.

19 May 2015

Transocean confirms further delay to newbuild jackup delivery

Transocean Ltd (“Transocean”) today confirmed an announcement that the company originally made in its Q1 2015 results regarding delivery of its five newbuild jackup rigs in Singapore. Transocean has agreed with Keppel FELS to extend the construction delay further than the initial six month delay that was agreed upon in February 2015. The first jackup, Transocean Cepheus is now scheduled to .... [+ read more] be delivered in Q1 2018, a full two years later than originally planned. Meanwhile the remaining units are scheduled to be delivered in Q3 2018, Q1 2019, Q3 2019 and Q1 2020.

18 May 2015

Ocean Rig and Eni complete drilling contract agreement

Ocean Rig UDW Inc. (“Ocean Rig”) today announced that in connection with the previously announced omnibus agreement with Eni Angola S.p.A (“Eni”), all closing connections including approvals by national authorities and signing of definitive documentation has been satisfied. The omnibus agreement was originally announced by Ocean Rig on the 8th January 2015. As a result of the completed agreement, the .... [+ read more] contract for the Ocean Rig Poseidon has been extended for a full year, until Q2 2017 and the unit now has a total contract backlog of USD367 million. Meanwhile the Eni has entered into a new contract for the Ocean Rig Olympia which is expected to commence drilling in Angola in Q3 2015 for a minimum period of eight months and a total contract value of USD91 million.

18 May 2015

Kosmos announces larger discovery at Tortue-1

Kosmos Energy (“Kosmos”) has announced that the Tortue-1 exploration well in Block C8, offshore Mauritania has encountered additional hydrocarbons whilst drilling to its total depth. Based on the preliminary analysis of drilling results, Tortue-1 has intersected approximately 10 meters (32 feet) of net hydrocarbon pay in the lower Albian section, which is currently interpreted to be gas. This is in addition .... [+ read more] to the previously announced 107 meters (351 feet) of net pay encountered in the Cenomanian, which was the primary objective. The well was drilled beyond the primary objective to obtain deeper stratigraphic information and enable seismic calibration of the Albian, which will be tested in subsequent wells. Down to total depth drilled, no water was encountered in the well. Brian F. Maxted, chief exploration officer, said: “We are encouraged by the presence of additional hydrocarbons in the deeper portion of the well. This suggests we have a working hydrocarbon system in both the Albian and Cenomanian sequences. While the Albian was not the primary objective of the Tortue-1 well, the presence of additional hydrocarbons in the Albian further de-risks other prospects in the Greater Tortue Complex which include primary reservoir targets in both the Albian and underlying Aptian.” Located approximately 285 kilometers southwest of Nouakchott in 2,700 meters of water, and drilled with the Atwood Achiever drillship, the Tortue-1 well was drilled at a total cost of approximately USD125 million to a total depth of approximately 5,100 meters. The Tortue discovery area has also been renamed Ahmeyim. Kosmos currently owns a 90% interest in the Ahmeyim discovery, along with Société Mauritanienne Des Hydrocarbures et de Patrimoine Minier (SMHPM) at 10%.

16 May 2015

VietGazprom contracts 'Deepsea Metro I'

Odfjell Drilling (“Odfjell”) has secured new a new contract for the Deepsea Metro I drillship by signing a contract with VietGazprom in Vietnam. The unit will work between blocks 130 and 131 offshore Vietnam. Contract commencement is expected to take place in mid Q3 2015. The contract duration is approximately 20 weeks, with an estimated contract value of USD40 million. The .... [+ read more] contract also includes options for two well testing periods with an estimated duration of 90 days each. "We are pleased to secure new employment for Deepsea Metro I in the current challenging market. Since it was delivered from yard in 2011 the drillship has provided safe, reliable and the highest quality of drilling performance for our previous clients. The rig has been unemployed since December 2014 and is currently positioned in South Africa. It will start mobilising for its new contract in Vietnam immediately," says Mr Simen Lieungh, CEO of Odfjell Drilling. The ultra-deepwater drillship, Deepsea Metro I, is owned by Golden Close Maritime Corp. Ltd., a company owned by Deep Sea Metro Ltd., a joint venture between Metro Exploration (60%) and Odfjell Drilling (40%). Odfjell Drilling is the manager of the vessel.

15 May 2015

Shell given approval to plug another Draugen well

The PSA has given AS Norske Shell (“Shell”) consent to use the Transocean Barents mobile drilling facility for plugging and abandonment of production well 6407/9-A-55 on the Draugen field. This is the second well on Draugen that Shell have been given approval to plug during the week, following the PSA’s approval of the plugging of the 6407/9-G-5 H well on the .... [+ read more] 13th May.

15 May 2015

OMV drills duster at Bjaaland prospect

OMV (Norge) AS, operator of production licence 537, is in the process of concluding the drilling of wildcat well 7324/8-2. The well was drilled about 6 kilometres southeast of oil discovery 7324/8-1 "Wisting" in the Barents Sea and 310 km north of Hammerfest. The purpose of the well was to prove petroleum in reservoir rocks from the Middle Jurassic to .... [+ read more] Late Triassic Age (the Stø and Fruholmen formations). The secondary exploration target was to prove petroleum in reservoir rocks from the Middle to Late Triassic Age (the Snadd formation). The well encountered about 15-metre thick reservoir rocks in the Stø formation with good reservoir quality and about 55-metre thick reservoir rocks in the Fruholmen formation with medium to good reservoir quality. The well also encountered about 10-metre thick reservoir rocks in the Snadd formation with good reservoir quality. The well is dry. Data acquisition and sampling has been carried out. This is the fourth exploration well in production licence 537. The licence was awarded in the 20th licensing round in 2009. Well 7324/8-2 was drilled to a vertical depth of 815 metres below the sea surface and was terminated in the Snadd formation from the Late Triassic Age. Water depth at the site is 394 metres. The well will now be permanently plugged and abandoned. Well 7324/8-2 was drilled by the Leiv Eriksson drilling facility, which is now scheduled to drill wildcat well 6507/11-11 in production licence 591 in the Norwegian Sea, operated by Tullow Oil Norge AS.

15 May 2015

Noble agrees to jackup rate reduction with Saudi Aramco

Noble Corporation (“Noble”) today released its updated fleet status and announced that the company reached an agreement with Saudi Aramco to reduce the operating dayrates for five jackup rigs. The dayrate reductions are effective from 1st January 2015 and run through the entirety of 2015 and will be applied over the remaining life of the existing contracts. The rigs in question .... [+ read more] are the Noble Scott Marks, Noble Roger Lewis, Noble Gene House, Noble Joe Beall and Noble Charles Copeland. The dayrates for the Noble Scott Marks and Noble Roger Lewis were reduced to USD169.5k whilst the remaining three jackup rates were reduced to USD65k. This announcement follows earlier agreements that Saudi Aramco negotiated with Rowan and Ensco for rate reductions in 2015.

15 May 2015

Suncor fails to find hydrocarbons with Beta Statfjord appraisal

Suncor Energy Norge AS, operator of production licence 375, has completed drilling of appraisal well 34/4-14 S in the oil discovery 34/4-11. The discovery was proven in 2010, and is located approximately 20 kilometres northwest of the Snorre field in the North Sea. The reservoir is in the Brent and Statfjord groups and, prior to drilling of appraisal well 34/4-14 S, .... [+ read more] the expected recoverable reserves were about 7 million Sm3 of oil and 0.7 billion Sm3 of gas. The purpose of well 34/4-14 S was to delineate the discovery proven with well 34/4-11 and delineated by well 34/4-13 S. The well encountered a reservoir in the Statfjord group from the Early Jurassic Age and proved 11 metres of net sandstone of good quality. The well is dry. Data acquisition and sampling has been carried out. This well is the third exploration well in production licence 375, awarded in APA 2005. The well was drilled to a vertical depth of 4532 metres below the sea surface and was terminated in the Lunde formation from the Late Triassic Age. The well will be permanently plugged and abandoned. Well 34/4-14 S was drilled by the Borgland Dolphin drilling facility, which is now scheduled to drill wildcat well 25/10-13 S in production licence 571, operated by Suncor Energy AS.

14 May 2015

JDC has started the drilling operation using HAKURYU-12

The new jack-up rig "HAKURYU-12" departed from Singapore on March 17, and sailed around the Cape of Good Hope in South Africa. After the loading of materials and equipment necessary to the operation at Trinidad and Tobago, she finally arrived to offshore Suriname in South America on May 8. Afterwards, she started the drilling operation based on the contract with TOS .... [+ read more] on May 14.

13 May 2015

Atlantica Tender Drilling announce early termination of 'Alpha' contract

Atlantica Tender Drilling Ltd (“Atlantica”) today announced that due to the depressed oil price environment, Total E&P Congo has elected to early terminate the contract for the Alpha. The contract is expected to come to reach its conclusion of the present well expected later this month. Atlantica intends to warm stack the Alpha offshore Congo (Brazzaville) in anticipation of future work .... [+ read more] in the area. The Alpha is presently being actively marketed to operators in both major tender assist regions: Southeast Asia and West-Africa.

13 May 2015

PSA approves use of 'Transocean Barents' on Draugen Field

A/S Norske Shell (“Shell”) has received consent to use the Transocean Barents mobile drilling facility to drill a production well on the Draugen field. Draugen is an oil field in the Norwegian Sea, around 150 km north of Kristiansund. Shell is the field's operator. Production on the field began in October 1993. The field has been developed using a fixed concrete .... [+ read more] facility with an integrated deck. Deposits in the vicinity are produced by subsea wells tied back to the Draugen facility. Shell has applied for consent to drill a new production well designated 6407/9-G-5 H. Water depth at the site is 289 metres. The well will be connected to a subsea pipeline system leading to the Draugen facility. Until this system is ready, the well will be shut off and monitored. Shell has now received consent to use the Transoceoan Barents mobile drilling facility for drilling, which is scheduled to begin on 30th May 2015 and last for 45 days.

13 May 2015

'Ocean Victory' arrives in Trinidad for BP contract

BP Trinidad and Tobago LLC (“BP”) has announced that the Ocean Victory semi-submersible drilling rig, owned and operated by Diamond Offshore Drilling Inc (“Diamond”), has arrived in Trinidad and Tobago after mobilising from the USA. The unit will now take on personnel, equipment and supplies, before moving to the offshore location of the Juniper field located 50 miles off the south .... [+ read more] east coast of Trinidad, where it is expected to commence drilling operations in mid-May. The Juniper project is BP’s first in subsea field development in Trinidad and will have a production capacity of approximately 590 million standard cubic feet a day (mmscfd). First gas from the facility is expected in 2017. The rig, which is capable of drilling to total depths of up to 25,000 feet, and in water depths of up to 6,000 feet, is under contract for an initial term of two years. It is expected to drill 5 subsea wells which will be tied into the Juniper platform. Ocean Victory has travelled 2,168 nautical marine miles in 23 days from Mississippi, US. This will be the third rig in operation on BP’s offshore facilities in Trinidad, joining the SKD Jaya and the Rowan EXL II.

13 May 2015

NPD approves Zumba prospect drilling

The Norwegian Petroleum Directorate (NPD) has granted Tullow Oil Norge AS a drilling permit for well 6507/11-11, cf. Section 8 of the Resource Management Regulations. Well 6507/11-11 will be drilled from the Leiv Eriksson drilling facility in position 65° 14' 16.06'' north and 7° 30' 39.31'' east completing wildcat well 7324/8-2 in production licence 537 for OMV (Norge) AS. The .... [+ read more] drilling programme for well 6507/11-11 concerns the drilling of a wildcat well in production licence 591. Tullow Oil Norge AS is the operator with an ownership share of 80 per cent. The other licensees are North Energy ASA (15 per cent) and Lime Petroleum Norway AS (5 per cent). The area in this licence consists of part of block 6507/8, part of block 6507/9 and part of block 6507/11. The well will be drilled about 14 kilometres southeast of the Heidrun field and about 220 kilometres west of the Njord field. Production licence 591 was awarded on 4 February 2011 (APA 2010). This is the first well to be drilled in the licence. The permit is contingent upon the operator having secured all other permits and consents required by other authorities before the drilling starts.

12 May 2015

Ocean Rig delays delivery of two newbuild drillships

Ocean Rig UDW Inc (“Ocean Rig”) today released its financial results for Q1 2015. The company posted a profit of USD41.1 million for the first three months of 2015, recovering from last year’s USD1.5 million first quarter loss. However, Ocean Rig’s Chairman and Chief Executive officer George Economou warned that “the market remains challenging with limited visibility of new contracts and .... [+ read more] is likely to remain through the near term”. With reference to this the company took the decision to delay the delivery of the Ocean Rig Crete and Ocean Rig Amorgos newbuild drillships until Q1 2018 and Q1 2019. Both units had previously been ordered to be delivered in 2017.

12 May 2015

'Eirik Raude' restarts Isobel Deep drilling

Rockhopper Exploration plc (“Rockhopper”), the oil and gas exploration and production company with interests in the North Falkland Basin and the Greater Mediterranean region, has announced the following operations update. The Erik Raude semisub rig has now completed repairs to its BOP control system and has undergone the subsequent re-testing of the BOP stack following its return to the Isobel Deep .... [+ read more] well location where drilling re-commenced on 11th May 2015. Since suspending operations on the Isobel Deep (14/20-1) well on 24th April 2015, the rig has spudded and suspended the Jayne East (14/15c-6) well at 541m mdrkb on 29th April 2015 and spudded and suspended the Chatham (14/10-10) well at 1388m mdrkb on 4th May 2015.

12 May 2015

Maersk announces discovery at Xana-1X

As operator of license 9/95 Mærsk Olie og Gas A/S (“Maersk Oil”) has drilled the exploration well Xana-1X (5604/26-7) in the northern part of the Danish North Sea. Xana-1X was drilled as a vertical well. The well proved the presence of hydrocarbons in Upper Jurassic sandstone. A comprehensive data and sample acquisition programme was carried out for further characterization of the .... [+ read more] discovery. The oil companies will now evaluate the results of Xana-1X and make plans for the additional work that is necessary to determine if the hydrocarbon discovery can be produced commercially. Xana-1X was spudded on 8th December 2014 with the jack-up rig Noble Sam Turner, where the water depth is 68 meters. The well terminated in Upper Jurassic clay stone at a depth of 5,071 meters below mean sea level. The well is now being plugged and abandoned. Subsequently the jack-up rig Noble Sam Turner will be moved to licence 8/06B for the drilling of the Jude-1 appraisal well.

12 May 2015

BOEM approves Shell's arctic exploration plan

After a comprehensive review and consideration of comments received from the public, stakeholders, and Federal and state partner agencies and tribes, the Bureau of Ocean Energy Management (“BOEM”) today conditionally approved Shell Gulf of Mexico, Inc.’s revised multi-year Exploration Plan (“EP”) for the Chukchi Sea. Among the conditions of approval is the requirement that Shell obtain all necessary permits from other .... [+ read more] state and federal agencies, including permits to drill from the Bureau of Safety and Environmental Enforcement (“BSEE”) and appropriate authorizations under the Marine Mammal Protection Act. Another condition of approval prevents Shell from commencing drilling operations until all Biological Opinions under the Endangered Species Act have been issued and requires all operations under the plan comply with the terms and conditions included in those Biological Opinions. The EP describes all exploration activities planned by the operator, including the timing of these activities, information concerning drilling vessels, the location of each planned well, and actions to be taken to meet important safety and environmental standards and to protect workers, resources, wildlife and access to subsistence use areas. In accordance with the National Environmental Policy Act, the review of the EP included the preparation of an Environmental Assessment and a subsequent Finding of No Significant Impact. Shell’s revised EP proposes the drilling of up to six wells within the Burger Prospect, located in approximately 140 feet of water about 70 miles northwest of the village of Wainwright. Shell will conduct its operations using the Noble Discoverer and Transocean Polar Pioneer units, with each rig providing relief-well capability for the other. The two drilling units and their supporting vessels will depart the Chukchi Sea at the conclusion of each exploration drilling season.

11 May 2015

PSA performs audit of Dolphin Drilling Ltd

From 14th to 16th April, the Petroleum Safety Authority (“PSA”) Norway carried out an audit of Dolphin Drilling Ltd’s (“Dolphin”) land organisation in the domains of structural safety and maritime systems. The objective of the audit was to monitor that Dolphin possesses a robust system for verifying structures and maritime systems, especially in relation to ageing mechanisms. During the audit, the .... [+ read more] PSA sought to elucidate how the safety of ageing facilities is handled and how learning from identified ageing mechanisms and elements in previous incidents is used in respect of structural safety and maritime systems for Borgland Dolphin, Bideford Dolphin and Bredford Dolphin. No non-conformities or improvement points were identified.

11 May 2015

PSA approves Lundin's plan to drill exploration well 7220/11-3

Lundin Norway AS (“Lundin”) has received consent to drill exploration well 7220/11-3. Lundin is the operator for production licence 609 in block 7220/11 in the Barents Sea. Lundin has applied for consent to drill exploration well 7220/11-3. Drilling is scheduled to begin in June 2015 and estimated to last 56 days, depending on whether a discovery is made. Water depth at .... [+ read more] the site is 397 metres. The well is to be drilled by the Island Innovator mobile drilling facility. This is a semi-submersible mobile drilling facility of the GM4000-WI type, built in 2012 at Cosco Zhoushan Shipyard in China. The facility is operated by Odfjell Drilling. It is registered in Norway and classified by DNV GL. Island Innovator was issued with an Acknowledgement of Compliance (AoC) by the PSA in August 2013.

11 May 2015

'West Telesto' reaches TD at Yolla-6

Origin Energy Limited (“Origin”), the Operator of the BassGas Joint Venture, today announced that the Yolla-6 production well, which spudded at 21:30 hours AEDT on 14th March 2015, had reached total depth of 3,653m Measured Depth Below Rotary Table (“MDRT”). The well was drilled using the West Telesto jack up rig, which will move back to complete drilling of the Yolla-5 .... [+ read more] well which it top hole drilled on the 10th March 2015. The Yolla-5 and Yolla-6 wells are being drilled as part of Stage 2 of the BassGas Mid Life Enhancement (“MLE”) project. Yolla-6 will be cased and completed before being commissioned for production via the BassGas production facility at Lang Lang, Victoria. The wells are being drilled from the Yolla Platform which is located in Bass Strait, approximately 140km off shore from Kilcunda, Victoria.

11 May 2015

Cairn Energy cements Senegal drilling programme

Cairn Energy PLC (“Cairn”) and its joint venture partners have submitted a three year evaluation work plan to the Government of Senegal including an initial programme of three firm and three optional exploration and appraisal wells, with drilling starting in Q4 2015 in Cairn’s new basin play offshore Senegal focused on the acreage around the SNE-1 discovery well. Cairn estimates that .... [+ read more] the existing two discoveries and the currently identified prospects and leads have an estimated mean risked resource base of more than a billion barrels. The company has selected the Ocean Rig Athena drillship for the drilling programme and is in the final stages of finalising the rig contract. The drillship is currently contracted to ConocoPhillips in Angola until June 2017 and it is not yet clear whether the contract will be a sublet or if Cairn is taking over part of ConocoPhillips’ contract. The firm three well programme is currently planned to include two appraisal wells of the SNE-1 discovery which will core and test the reservoir, as well as one shelf exploration well. There will also be a 2,000km2 3D seismic data acquisition campaign over the Sangomar and Rufisque blocks to help fully map the prospectivity of the contract area. A work programme and budget for the three optional wells will be presented to joint venture partners in Q3 2015. Targets for these wells will be drawn from a combination of further evaluation of the SNE-1 discovery, additional exploration in the shelf region, and exploration in the acreage around FAN-1. Drilling plans for these wells will be subject to ongoing FAN studies and the results of the first three firm wells. Simon Thomson, Chief Executive of Cairn said: “Cairn made two significant discoveries offshore Senegal in 2014 proving a hydrocarbon system in a new and emerging Atlantic Margin Basin. We are excited about the exploration and appraisal opportunity of this world class asset. We have now submitted a three year evaluation work plan to the Government of Senegal which is designed to lay the foundation for a long term multi-field, multi phase exploitation plan. Our focus will be to add value in Senegal within a balanced, well funded company. We are well placed to take advantage of this exciting opportunity as we build on the success of last year.”

11 May 2015

Paragon announces contract cancellations in Mexico

Paragon Offshore plc. (“Paragon”) has announced that on the 6th May 2015, the company received written notices of termination from PEMEX – Exploracion y Produccion (“Pemex”) for the Paragon L1113 and Paragon B301 jackup rigs. Pemex exercised its 30 days right to terminate notice and the contracts are due to come to a conclusion in late May 2015. .... [+ read more]

8 May 2015

PSA approves VNG exploration plan for PL 586

VNG Norge (“VNG”) has received consent to drill two exploration wells 6406/12-4 S and 6406/12-4 A in the Norwegian Sea. VNG is the operator for production licence 586 in block 6406/12 in the Norwegian Sea. The field is around 83 kilometres from the Norwegian coast at Frøya and 61.4 kilometres south-west of Draugen. Water depth at the site is 319 metres. .... [+ read more] Drilling is scheduled to begin in June 2015 and estimated to last 52 days. In the event of a discovery, the activity may last a further 84 days for well testing. Drilling is to be carried out using Transocean Arctic, a semi-submersible drilling facility owned and operated by Transocean. It was built by Mitsubishi Heavy Industries in Japan in 1987, and substantially upgraded in 2004. It was issued with an Acknowledgement of Compliance (AoC) by the PSA in July 2004.

8 May 2015

Statoil to plug Kristin field well

Statoil has received consent to use Scarabeo 5 for permanent plugging of well 6506/11-N-4 H on the Kristin field. Statoil has allocated up to 27 days for the activity, which will start in mid-May 2015. Water depth at the site is 367 metres. Scarabeo 5 is a type ME 4500 drilling facility and was built at the Fincantieri Shipyard in Genoa, .... [+ read more] Italy in 1990. It is operated by Saipem Norwegian Branch (Saipem). It is registered in the Bahamas and classified by ABS.

8 May 2015

Tullow set to spud Zumba prospect

Tullow Oil Norge AS (“TONAS”) has received consent for exploration drilling of well 6507/11-11. Tullow Oil Norge AS is the operator for production licence 591 in block 6507/11 in the Norwegian Sea. TONAS has applied for consent to drill exploration well 6507/11-11 in a prospect named Zumba. Drilling is scheduled to begin in May/June 2015 and estimated to last 50 days. .... [+ read more] In the event of a discovery, the activity may last a further 8 days for well testing. Water depth at the site is 272 metres.

7 May 2015

Talisman set to plug wells on Varg field

Talisman Energy AS (“TENAS”) has received consent to use the Mærsk Giant jackup for well plugging on the Varg field. TENAS received consent to use Mærsk Giant for plugging wells 15/12-A-2, A-4, A-9, A-11, A-12, A-13, A-15 and A-16 on the Varg field. TENAS has allocated up to 153 days for the activity, which will start in mid-May 2015. Water depth .... [+ read more] at the site is 367 metres. Varg is an oil field located south of Sleipner East in the central sector of the North Sea. The field will be produced using the Petrojarl Varg production vessel, which has integrated oil storage and is tied to the Varg A well-head facility.

7 May 2015

Karoon completes Echidna-1 drilling

Karoon Gas Australia Ltd (“Karoon”) has announced that the company has completed its production tests on the Echidna-1 well in the Santos Basin, Brazil. The test produced a facility constrained stabilised flow rate of 4,650 bopd from the Palocene reservoirs with a flowing well head pressure of 504 psig on a 1” choke. With reference to the Olinda Star contract, Karoon .... [+ read more] chose not to take up the final well option and will now release the unit.

6 May 2015

Repsol given approval to drill Hagar prospect

Repsol Exploration Norge AS (“RENAS”), the operator for production licence 642 in block 6306/5 in the southern Norwegian Sea has been given approval to spud an exploration well. Exploration well 6306/5-2 is to be drilled in a prospect called Hagar. The drill site is 80 km south-west of the Draugen field, and 65 km west of Smøla. Water depth at .... [+ read more] the site is 226 metres. Drilling is scheduled to begin in May 2015 and estimated to last 64 days, depending on whether a discovery is made. The well will be drilled by Bredford Dolphin, which is a mobile drilling facility of the Aker H-3 type. It was built in 1977 and significantly upgraded in 1999. The facility is registered in Singapore and classified by DNV GL.

5 May 2015

Otto Energy contracts 'Maersk Venturer' for Philippines drilling

Otto Energy Ltd (“Otto”) has announced that it has signed a contract to secure the Maersk Venturer drillship for its Hawkeye-1 exploration well in the Philippines. The window of commencement for mobilisation to the Hawkeye-1 drilling location is between 17th July and 15th August 2015. Otto is in the process of securing key services and equipment in the build up to .... [+ read more] mobilisation. Once it has reached the drilling location, the Maersk Venturer is expected to take 23 days to drill the well until rig release. The unit is currently ready stacked in Labuan, Malaysia.

5 May 2015

NDC contracts two premium jackups from Ensco for Abu Dhabi (UAE) drilling

Ensco plc (“Ensco”) has announced that it has entered into a three-year contract with National Drilling Company (“NDC”) for the ENSCO 110 jackup rig. This newbuild rig is scheduled to commence operations later this month offshore Abu Dhabi (UAE) at a rate of approximately USD114,000 per day. NDC has also contracted ENSCO 104 for a similar three-year term at a day .... [+ read more] rate of USD114,000. The rig is mobilising to the Middle East from the Asia Pacific region and is scheduled to commence its new contract in late-June 2015. Chief Executive Officer Carl Trowell commented, “We are pleased to extend our relationship with NDC. The Middle East is the largest market for premium jackups, and we continue to invest in new rig technology for the benefit of customers. ENSCO 110 is based on the Keppel FELS B Class Bigfoot design, which is capable of working at water depths up to 400 feet with a maximum drilling depth of 30,000 feet. The rig has a nominal variable deck load of 7,500 kips and a cantilever load of 2,500 kips. It includes a 1.5 million-pound derrick, TDS-8 top drive and 4-ram 15,000-psi BOP. Ensco customized the rig to add dual drilling fluid capability and upgraded the living quarters to accommodate 150 persons on board. ENSCO 104 is based on the KFELS Class B design. The rig operates in water depths up to 400 feet with a maximum drilling depth of 30,000 feet. The rig has a variable deck load of 8,025 kips and a cantilever load of 1,675 kips. It includes a 1.5 million-pound derrick, TDS-8 top drive and 4-ram 10,000-psi BOP.

5 May 2015

Statoil drilling at Bister prospect approved

The Norwegian Petroleum Directorate has granted Statoil Petroleum AS a drilling permit for wellbore 6407/8-7, cf. Section 8 of the Resource Management Regulations. Wellbore 6407/8-7 will be drilled from the Transocean Spitsbergen drilling facility in position 64° 23' 4.06'' north and 7° 33' 42.8'' east. The drilling programme for wellbore 6407/8-7 concerns the drilling of a wildcat well in production .... [+ read more] licence 348 C. Statoil Petroleum AS is the operator with an ownership interest of 35 per cent. The other licensees are GDF SUEZ E&P Norge AS (20 per cent), E.ON E&P Norway AS (17.5 per cent), Core Energy AS (17.5 per cent), Faroe Petroleum Norway AS (7.5 per cent) and VNG Norge AS (2.5 per cent). The area in this licence consists of part of block 6407/8. The well will be drilled about 4.5 kilometres north of the Hyme field and about 22 kilometres northeast of the Njord field. Production licence 348 C was awarded on 13 February 2015. This is the first well to be drilled in the licence. The permit is contingent upon the operator having secured all other permits and consents required by other authorities before the drilling starts.

4 May 2015

Apache negotiates rate reduction for final two months of future contract

Apache Corporation (“Apache”) has negotiated a reduced dayrate with Diamond Offshore Drilling Inc (“Diamond”) on its future contract for the Ocean Monarch semisubmersible drilling rig. The unit which is expected to begin its 18 month contract in Australia for Apache in June 2015 will see its dayrate reduce from USD410,000 to USD350,000 for the final two months of the 18 month .... [+ read more] contract.

4 May 2015

Diamond announces new wave of rig retirements and stacking activity

Diamond Offshore Drilling Inc. (“Diamond”) today released the company’s updated fleet status report alongside its financial results for Q1 2015. Diamond announced a further wave of rig retirements and cold stacking amid the current downturn in the drilling market. The offshore rig manager retired three semisub units, the Ocean Worker, Ocean Yorktown and Ocean Saratoga. The three retired units had an .... [+ read more] average age of 37 years. Meanwhile Diamond also cold stacked the Ocean Star, Ocean Princess, Ocean Nomad and Ocean Spur. Diamond has been one of the most active rig managers in terms of stacking and retirement activity thus far in 2015.

1 May 2015

Atwood delays delivery of 'Atwood Admiral'

Atwood Oceanics (“Atwood”) has announced that it has opted to delay the delivery of its newbuild Atwood Admiral drillship from September 2015 until March 2016. Atwood announced a few months ago that it had agreed to potentially push back the delivery of the Atwood Admiral and Atwood Archer drillships from their current delivery schedule amid the slowdown in the offshore drilling .... [+ read more] market. The unit which is being constructed at Daewoo Shipbuilding and Marine Engineering’s (“DSME”) shipyard in Okpo, South Korea and Atwood has a further option to delay delivery until September 2016 if required.

1 May 2015

Lamprell delivers 'Butinah' jackup rig

Lamprell Plc (“Lamprell”) has announced the completion of the construction of the Butinah jackup drilling rig for Abu Dhabi’s (UAE) National Drilling Company (“NDC”). The Butinah rig departed Lamprell’s Hamriyah shipyard on the 1st May 2015 and is enroute to its drilling location on the Zakum field offshore Abu Dhabi (UAE). The Butinah rig joins its sister rigs, the Makasib, Muhaiyimat, .... [+ read more] Qarnin, Marawah and the Shuwehat, all of which were built to LeTourneau’s Super 116-E rig design.

1 May 2015

Odfjell Drilling expects Brazilian newbuilds to be delayed by one year

Odfjell Drilling (“Odfjell”) today released its annual report for 2014. Within the report Odfjell highlighted its ownership of three of the drillships being constructed as part of Sete Brasil’s Brazilian drillship campaign. Odfjell is involved with the construction of three drillships in Brazil, that would be managed by Odfjell Galvao (Odfjell owns 50% of the management company) following construction at the .... [+ read more] Estaleiro Jurong Aracruz shipyard in Brazil. Whilst construction of the first unit is progressing, there is risk and uncertainty related to the newbuild programme in Brazil linked to Sete Brasil’s financial troubles. Odfjell expects that each of the drillship projects will be delayed by at least one year compared to the original delivery plan.

1 May 2015

Hercules extends 'Hercules 261' contract for another month

Hercules Offshore, Inc. (“Hercules”) has announced that it has received a notice from Saudi Aramco extending the termination date of its drilling contract for the Hercules 261, to May 31st, 2015. This is the second termination date extension that Saudi Aramco has issued for the Hercules 261. Previously the contract was due to expire on the 27th March 2015 and then .... [+ read more] the 30th April 2015, following notice that Saudi Aramco gave Hercules in February 2015. As previously disclosed, we are in the process of seeking a basis for continuing the Hercules 261 contract.

30 Apr 2015

KrisEnergy completes Rayrai-1 well

KrisEnergy Ltd. (“KrisEnergy”), has provided an update to the drilling of the Rayrai-1 exploration well in block G10/48 in the Gulf of Thailand. KrisEnergy announced that the Rayrai-1 well has reached a total depth of 6,382 feet (1,945 metres) measured depth and intersected approximately 50 feet true vertical depth of net oil-bearing sandstones. The well, which is located in 170 feet .... [+ read more] of water was drilled by the Key Gibraltar jackup rig.

30 Apr 2015

Keppel updates status of Sete Brasil rig orders

Amid the recent concern surrounding Sete Brasil’s numerous rig orders in Brazil, Keppel Offshore & Marine (“Keppel”) has released a statement indicating that at the 31st March 2015, the first three of the six DSS 38E semisubs being constructed for Sete Brasil at the BrasFELS shipyard in Brazil were around 89%, 58% and 32% complete. Keppel indicated that the company has .... [+ read more] received payments up to November 2014, alongside a 10% down payment for the three units yet to begin construction. Keppel has indicated that it does not expect Sete Brasil to cancel the six units on order at BrasFELS and has spoken to the rig owner to explore the possibility of slowing down construction of the orders until Sete Brasil can secure sufficient financing for the project.

30 Apr 2015

'COSLProspector' goes to work for CNOOC

On 30th April 2015, the COSLProspector semisub officially left the deep-water wharf of CIMC Raffles and joined the deepwater fleet of CNOOC. COSLProspector is the fourth deepwater semisubmersible drilling rig delivered by CIMC Raffles for China Oilfield Services Limited (“COSL”). It can operate in all sea areas except for the arctic. The operational water depth is up to 1,500 meters, whilst .... [+ read more] drilling depth is up to 7,600 meters, designed temperature -20?, accommodation for 130 personnel and the maximum variable deck load of 5,500 tons. The unit is equipped with most advanced National Oilwell Varco (“NOV”) drilling system and DPS-3 dynamic position system and is classed by both DNV and CCS. The COSLProspector is also classified for operations in Norway. Since the delivery of the unit on 19th November 2014, an 80 strong engineering team has been dedicated to the preparation project, including preparing the ROV system, combustion beam system and mud log system. 50 of them spent Chinese Spring Festival on the rig.

30 Apr 2015

Chevron announces gas discovery in Australia

Chevron Australia Pty Ltd announced today further drilling success in the Greater Gorgon Area located in the Carnarvon Basin, a premier hydrocarbon basin offshore northwest Australia. The Isosceles-1 exploration discovery well encountered approximately 134 metres (440 feet) of net gas pay in the Triassic Mungaroo Sands in 968 metres of water (3,175 feet). The well fulfilled the second year work commitment .... [+ read more] in the exploration program. It is located in the WA-392-P permit area approximately 95 kilometres (60 miles) northwest of Barrow Island, off the coast of Western Australia. “This discovery is a continuation of our exploration success and further positions our company as a key supplier for future liquefied natural gas (LNG) demand in the Asia-Pacific region,” said Melody Meyer, president, Chevron Asia Pacific Exploration and Production Company. Roy Krzywosinski, managing director, Chevron Australia, said: “This discovery in the Greater Gorgon Area is an important addition to our portfolio and highlights the industry-leading results of our exploration program in Australia.” Chevron Australia is the operator of WA-392-P with a 50 percent interest while Shell Australia and Mobil Australia Resources each hold a 25 percent interest.

29 Apr 2015

Murphy fails to find hydrocarbons with Munia prospect

Murphy Oil Corporation (“Murphy”) has announced within the release of its first quarter 2015 earnings that its third and final exploration well in the Perth Basin called the Munia prospect is a dry hole and has been plugged and abandoned. All three exploration wells (Koel, Cisticola and Munia) were classified as dry holes and Murphy recorded a dry hole expense of .... [+ read more] USD31.8 million in Q1 2015 for this drilling programme. The Atwood Falcon was used for the drilling programme and the unit has now gone to work for BHP Billiton.

29 Apr 2015

BP confirms start of Quad 204 drilling programme

BP, on behalf of the Schiehallion co-venturers Shell and OMV, is pleased to announce the start of drilling on the Loyal field by the newbuild, semi-submersible Deepsea Aberdeen, marking the start of a seven year drilling campaign west of Shetland. Deepsea Aberdeen is contracted to drill wells across the Schiehallion and Loyal fields, as part of the Quad204 development. The sixth-generation, .... [+ read more] dual derrick rig is the newest addition in Odfjell Drilling’s fleet of mobile offshore drilling units. It has been designed to the highest international safety standards to operate in harsh environments, carrying out ultra-deepwater drilling in depths up to 3,000m. The Deepsea Aberdeen will initially drill two producer wells and one injector well on Loyal, before moving onto Schiehallion to continue drilling activities. Five wells are planned to be drilled prior to first oil from the new Glen Lyon floating, production, storage and offload (FPSO) vessel at the end of 2016.

29 Apr 2015

PSA approves 'Transocean Arctic' to drill Wintershall exploration well 35/12-5

Wintershall has received consent to drill exploration well 35/12-5 in the northern part of the North Sea. Wintershall is the operator for production licence 378 in block 35/12 in the northern North Sea. Exploration well 35/12-5 is to be drilled in a prospect called Crossbill. The drilling site is around 10 km south-east of the Skarfjell well 35/9-7 and 12 km .... [+ read more] SSW of the Gjøa platform. Water depth at the site is 353 metres. Drilling is scheduled to begin in May 2015 and estimated to last 57 days. A possible sidetrack will take a further 113 days.

29 Apr 2015

PSA audits Songa Cat-D rig anchor chains

On 26th and 27th February 2015, the Petroleum Safety Authority Norway (“PSA”) carried out an audit of Songa Offshore's follow-up and management of the fabrication of the anchor chains for the Cat D rigs. The objective of the audit was to verify that the fabrication of anchor chain was being managed, followed up and performed in compliance with the regulations. The .... [+ read more] result of the audit was that, no non-conformities were identified. The audit concluded that the following improvements could be made; supply follow-up, planning and documentation of inspections and recording and documentation of repair grinding. The four Cat-D rigs are currently under construction as Daewoo Shipbuilding and Marine Engineering’s (“DSME”) shipyard in Okpo, South Korea.

28 Apr 2015

Wintershall makes small oil discovery in Norway

Wintershall Norge AS, operator of production licence 589, is about to complete drilling of wildcat well 6406/2-8. The well proved oil. The well was drilled about 20 kilometres south of the Kristin field in the Norwegian Sea and 190 kilometres northwest of Kristiansund. The objective of the well was to prove petroleum in Lower to Middle Jurassic reservoir rocks (Båt .... [+ read more] and Fangst groups). The well encountered two oil columns over an approx. 130-metre interval in the Båt and Fangst groups in sandstone of generally poor reservoir quality. Preliminary estimation of the size of the discovery is between one and eight million standard cubic metres (Sm3) of recoverable oil equivalents. The licensees will assess the discovery with regard to further follow-up. The well was not formation tested, but extensive data acquisition and sampling have taken place. This is the first exploration well in production licence 589, which was awarded in APA 2010. The well was drilled to a vertical depth of 4655 metres below the sea surface, and was terminated in red sandstone layers in the Middle to Upper Triassic (“Red beds”). Water depth is 262 metres. The well will now be permanently plugged and abandoned. Well 6406/2-8 was drilled by the Transocean Arctic drilling facility, which will now drill wildcat well 35/12-5 S in production licence 378 in the North Sea, where Wintershall Norge AS is the operator.

28 Apr 2015

Wintershall set to spud wildcat well in PL 378

The Norwegian Petroleum Directorate has granted Wintershall Norge AS a drilling permit for well 35/12-5 S, cf. Section 8 of the Resource Management Regulations. Well 35/12-5 S will be drilled from the Trancocean Arctic drilling facility at position 61°13`01.65" north and 03°49`39.29" east, after completing the drilling of wildcat well 6406/2-8 for Wintershall Norge AS in production licence 589. The .... [+ read more] drilling programme for well 35/12-5 S relates to the drilling of a wildcat well in production licence 378. Wintershall Norge AS is the operator with an ownership interest of 45 per cent. The other licensees are Capricorn Norge AS (20 per cent), Explora Petroleum AS (17.5 per cent) and Talisman Energy Norge AS (17.5 per cent). The area in this licence is composed of parts of block 35/12. The well will be drilled about 80 kilometres southwest of Florø. Production licence 378 was awarded on 6 January 2006 (APA 2005). This is the fifth well to be drilled in the licence. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

28 Apr 2015

Lamprell wins first firm newbuild rig order of 2015

Lamprell Plc. (“Lamprell”), has announced that National Drilling Company ("NDC"), Abu Dhabi, has exercised one of its existing options and awarded a contract to Lamprell for the construction and delivery of a high-specification jackup drilling rig. Lamprell has previously been awarded contracts by NDC for a series of eight rigs and this will be the ninth rig constructed of the same .... [+ read more] design. The LeTourneau-designed, Super 116E (Enhanced) Class mobile offshore drilling unit will be constructed at Lamprell's facility in Hamriyah, United Arab Emirates (UAE), with a planned delivery in Q2 2017. As previously announced, NDC has further options for Lamprell to build up to an additional two jackup rigs of the same design, which have been extended to 3Q 2015. James Moffat, Chief Executive Officer, Lamprell, said: "I am delighted to be able to announce this new award from NDC, thereby extending our on-going relationship with our largest client by way of a ninth new build jackup rig in the series. This is particularly pleasing given the backdrop of a challenging market environment. We are proud of the continuing confidence that NDC has shown in our track record for delivering high quality work competitively and to schedule and this consistent focus on client satisfaction is one of Lamprell's key strengths. We take this opportunity to thank NDC for this further business. The award of this newbuild is also the first newbuild rig order placed thus far in 2015 and follows the news that Abu Dhabi National Oil Company (“Adnoc”) is looking to boost its offshore production through the spending of over USD25 billion over the next 25 years. Adnoc is also looking to increase its drilling plans and potentially contract more offshore rigs in order to meet this demand.

28 Apr 2015

Statoil given green light to drill Bister prospect

Statoil Petroleum AS (“Statoil”), the operator of production licence 348 in block 6407/8 in the Norwegian Sea has been given approval to drill exploration well 6407/8-7 in Norway. Exploration well 6407/8-7 is to be drilled in a prospect called Bister. The drilling site is 80 km from the nearest mainland at Mausund, north of Frøya in the county of Sør-Trøndelag. .... [+ read more] Water depth at the site is 259 metres. Drilling is scheduled to begin in May 2015 and estimated to last 29 days, depending on whether a discovery is made. Drilling is to be performed by Transocean Spitsbergen, which is a semi-submersible mobile drilling facility of the Aker H-6e type.

27 Apr 2015

Kosmos makes significant gas find

Kosmos Energy (“Kosmos”) has announced that the Tortue-1 exploration well, drilled to test the Tortue West prospect, which forms part of the Greater Tortue Complex, in Block C-8 offshore Mauritania has made a significant, play-opening gas discovery. Based on the preliminary analysis of drilling results and intermediate logging to a depth of 4,630 meters, Tortue-1 has intersected 107 meters (351 feet) .... [+ read more] of net hydrocarbon pay. A single gas pool was encountered in the primary Lower Cenomanian objective. The Lower Cenomanian is comprised of three excellent quality multi-Darcy reservoirs totaling 88 meters (288 feet) in thickness over a gross hydrocarbon bearing interval of 160 meters (528 feet). A fourth zone 19 meters (62 feet) thick was penetrated within the secondary Upper Cenomanian target over a gross hydrocarbon bearing interval of 150 meters (492 feet). Andrew G. Inglis, chairman and chief executive officer, said: “Volumetrically, the Tortue-1 well has far exceeded our pre-drill expectations and has discovered a large scale gas resource. Our seismic imaging indicates the areal extent of Tortue West could cover approximately 90 square kilometres that will be better defined with appraisal drilling. Importantly, given the results and excellent well-to-seismic calibration, the Tortue-1 well has significantly de-risked our large and under-explored 27,000 square kilometre deepwater position in Mauritania. Our acreage offers substantial follow-on prospectivity including a diverse range of Cenomanian as well as deeper Cretaceous plays and fairways with strong dependency.” An appraisal program is being planned to delineate the Tortue West discovery. In addition, the Marsouin-1 exploration well, located in the central part of Block C-8, is expected to spud in the third quarter of 2015. An exploration program is also being formulated to test the other prospects in the Greater Tortue Complex, which extends into the St. Louis Offshore Profond Block in Senegal, including the Tortue East and Tortue North prospects. In support of this program, a 3D seismic survey acquired over our Senegal blocks in 2014 is currently being processed and interpreted. Located approximately 285 kilometres southwest of Nouakchott in 2,700 meters of water, and drilled with the Atwood Achiever drillship, the Tortue-1 well is now drilling to the planned total depth of approximately 5,250 meters. Kosmos currently owns a 90% interest in the Tortue Prospect, along with Société Mauritanienne Des Hydrocarbures et de Patrimoine Minier (SMHPM) at 10 percent. Since 2012, Kosmos has held rights to conduct exploration in the C-8, C-12 and C-13 contract areas under production sharing contracts with the Government of Mauritania. In March 2015,Chevron Mauritania Exploration Limited, a wholly owned subsidiary of Chevron Corporation (NYSE: CVX), acquired a 30% non-operated interest in the C-8, C-12 and C-13 contract areas under production sharing contracts. Chevron has an option to elect to participate at a 30% interest in the Tortue Prospect, subject to Chevron paying a disproportionate share of their costs related to the Tortue-1 exploration well. The blocks are contiguous, range in water depth between 1,000 and 3,000 meters, and have combined acreage of approximately 27,000 square kilometers.

24 Apr 2015

KrisEnergy spud Rayrai-1 exploration well

KrisEnergy Ltd. (“KrisEnergy”), an independent upstream oil and gas company, has announced that the company has begun drilling operations at the Rayrai-1 exploration well in block G10/48 in the Gulf of Thailand. The Rayrai-1 well is located in 52 metres of water and is projected to be drilled to a total depth of 1,945 metres. Following the completion of the exploration .... [+ read more] well, KrisEnergy will use the Key Gibraltar jackup to drill 15 development wells on the Wassana oil field located in the same block.

24 Apr 2015

Premier runs into trouble whilst drilling Isobel Deep

Rockhopper Exploration plc (“Rockhopper”), the oil and gas exploration and production company with interests in the North Falkland Basin and the Greater Mediterranean region, is providing an update on the operations on the 14/20-1 Isobel Deep well ("Well") that was spudded, by Premier Oil as operator, on 8th April 2015. Following successful setting of the 13 3/8" casing .... [+ read more] string at a depth of 1273.9m mdrkb, the Well has encountered problems with the BOP stack as a result of equipment malfunction which has required the Well to be suspended and BOP stack recovered for the necessary repairs. The Operator has decided to move the rig and set conductors at the Chatham and Jayne East locations. The rig will return to the Isobel Deep location to continue drilling on completion of BOP repairs and a further operational update will be issued at that time. No spud announcements will be made for the Chatham or Jayne East wells but information on the setting of conductors will be made in the next operational update.

23 Apr 2015

PSA completes 'Scarabeo 8' investigation

The PSA’s investigation of the incident on Scarabeo 8 during February 2015, when a man fell overboard, is now completed. Several regulatory breaches were identified. A man fell overboard from the mobile drilling unit Scarabeo 8 at about 04.00 on Friday 20th February 2015.The incident occurred when subsea personnel were preparing to bring the blowout preventer (BOP) back into service after .... [+ read more] about four weeks of maintenance. Two subsea engineers were working in the moonpool area at the time of the incident. They entered the BOP carrier used to move the unit between the well centre and the parked position. One of the subsea engineers descended the ladder which leads to a small access platform on the carrier. As he stepped off the ladder onto the grating below, he fell through a gap directly into the sea 13.5 metres below. The other subsea engineer observed the fall and managed to throw out a lifebuoy. The man-overboard alarm was sounded via Scarabeo 8’s control room to the Esvagt Aurora standby ship. Personnel on the latter mobilised its MOB boat and picked up the person from the water. He was flown by helicopter from the standby ship to hospital for a check and treatment. No serious injuries were found. The PSA quickly decided to investigate the incident. This investigation has sought to clarify the course of events, the direct and underlying causes and the actual and potential consequences, and possibly identify breaches of the regulations. The direct cause of the incident was the missing grating on the BOP carrier platform, probably as a result of high seas ahead of the incident.

22 Apr 2015

Coastal Contracts sells 'Coastal Driller 4001'

Coastal Contracts Bhd (“Coastal”) has announced that its wholly-owned subsidiary, Thaumas Marine Pte Ltd has secured a contract for the sale of a single jackup rig (Coastal Driller 4001) for approximately RM807 million (USD221 million). Coastal did not announce the buyer of the jackup rig, instead choosing to refer to it as “a reputable oil company”. However, it is believed to .... [+ read more] be Sinopec who were apparently leaning towards purchasing the jackup in January 2015 and renaming it Kan Tan 7. The jackup will be delivered in Q3 2015. Coastal also announced that it is discussions about potential charters for its second newbuild jackup, due to be delivered in Q4 2015 from CIMC Raffles in China.

22 Apr 2015

Saudi Aramco reduces wave of jackup rates - Rowan

Both Ensco Plc. (“Ensco”) and Rowan Companies Plc. (“Rowan”) have announced agreements with Saudi Aramco to reduce dayrates for a combined 12 jackups (five Rowan jackups and seven Ensco jackups). The wave of rate reductions for Rowan’s five units began on the 1st March 2015 and will last 12 months until 1st March 2016. Meanwhile the reductions for Ensco’s began in .... [+ read more] April 2015 and run until January 2016. Rates have been reduced from 9% up to 32% in some cases for the 12 jackups. The announcement of rate reductions for these units is expected to be echoed by other rig managers that have units on contract with Saudi Aramco.

22 Apr 2015

Det Norske completes two Ivar Aasen appraisal wells

Det norske oljeselskap AS, operator of production licence 001 B, has completed drilling of appraisal wells 16/1-21 S and 16/1-21 A on the Ivar Aasen field. The field is located in the central part of the North Sea and was proven in 2008. The size of the field prior to drilling of these two appraisal wells was 24 million standard cubic .... [+ read more] metres (Sm3) of recoverable oil, 1 million Sm3 of recoverable condensate and 4.5 billion Sm3 of recoverable gas. The primary target for wells 16/1-21 S and 16/1-21 A was to investigate reservoir rocks and reservoir quality, as well as the extent of an overlying gas cap in the eastern part of the field in Middle Jurassic to upper Triassic reservoir rocks (the Hugin, Sleipner and Skagerrak formations, as well as the Statfjord group). In addition, 16/1-21 S had a secondary exploration target in overlying Paleocene reservoir rocks (the Heimdal formation). 16/1-21 S encountered a total oil column of 54 metres, of which 25 metres were of good to very good reservoir quality in the Skagerrak formation. The oil is undersaturated, which is also the case in the eastern part of the field (16/1-16 and 16/1-16 A). The gas/oil ratio (GOR) in the oil zone is 130-145 Sm3/Sm3. The oil/water contact was not encountered, but was calculated at approx. 2436 metres, which is 2 metres deeper than previously assumed in the Skagerrak formation. Gas was not encountered in the well. In the Heimdal formation, the well encountered 27 metres of aquiferous sandstone of good to very good quality. 16/1-21 A encountered a total oil column of 41 metres and a 4-metre gas column, of which a total of 29 metres was of very good reservoir quality in the Sleipner and Skagerrak formations. The oil in the Sleipner formation is saturated, while the oil in the Skagerrak formation is largely undersaturated. The oil/water contact was not encountered. The well results have yielded valuable information as regards the final location of production and injection wells. Further work going forward will integrate the new data and contribute to increased field understanding. The Ivar Aase field field consists of production licences 001 B, 028 B, 242, 338 BS and 457. The Plan for Development and Operation (PDO) was submitted to the Ministry of Petroleum and Energy on 21 December 2012. Extensive data acquisition and sampling have been carried out. These are the fourth and fifth appraisal wells in production licence 001 B. This production licence was carved out of production licence 001 on 15 December 1999. PL001 was originally awarded on 1 September 1965 (round 1-A). Wells 16/1-21 S and 16/1-21 A were drilled to measured depths of 2630 and 3313 metres, respectively, and vertical depths of 2530 and 2463 metres below the sea surface. Both were terminated in the Skagerrak formation in the Upper Triassic. The wells have been permanently plugged and abandoned. Water depth at the site is 113 metres. The wells were drilled by the Maersk Interceptor drilling facility, which will now continue drilling appraisal well 16/1-22 S in the western part of the Ivar Aasen field.

21 Apr 2015

'Deepsea Aberdeen' begins drilling contract on Quad 204 field development

Odfjell Drilling has announced that today, the Deepsea Aberdeen semisub commenced drilling operations under its 7-year contract with BP on the Quad 204 field development project West of Shetland, UK. Deepsea Aberdeen is the latest addition to Odfjell Drilling’s fleet of ultra-deepwater and harsh environment mobile offshore drilling units. The rig was delivered from the DSME yard in South Korea in .... [+ read more] November 2014. The start of drilling operations of Deepsea Aberdeen marks another step in the development of Odfjell Drilling’s activities in the UK and harsh environment offshore regions. The rig design is based on our more than 40 years’ experience of drilling in the North Sea. Our offshore crew and our onshore organisation in UK are looking forward to working collaboratively with BP over the next seven years on the Quad 204 development, says CEO of Odfjell Drilling, Simen Lieungh.

20 Apr 2015

Karoon confirms oil at Echidna-1

Karoon Gas Australia Ltd (“Karoon”) has announced that wireline testing at the Echidna-1 well confirmed a 213 metre gross oil column across the Paleocene and Maastrichtian ageed reservoirs. On the 20th April 2015, the Echidna-1 well completed its wireline program and was now preparing for the commencement of a production testing program within the Paleocene reservoir section. Karoon Managing Director Mr. .... [+ read more] Robert Hosking said, “The Echidna discovery represents another significant achievement for karoon. Echidna adds incremental resource to Karoon’s discovered Kangaroo oil field which further supports Karoon’s ambitions to develop an integrated production hub in the Santos Basin.

20 Apr 2015

'Satti' jackup rig launched in Caspian Sea

At the Caspian shipyard Ersai, located in Kuryk village of Mangistau Oblast the dry-dock launching of the Satti jackup drilling rig took place, the keel of which was laid down on May 8th, 2013. Rakimbek Amirzhanov, Deputy Governor of Mangistay Oblast said that it was the first jackup drilling rig built in Kazakhstan. Upon completion the Satti jackup will be capable .... [+ read more] of working in deeper waters than the Caspian Explorer drilling barge. It is also fit for operating in the Iranian sector of the Caspian Sea where the depth is over 40 metres. The Satti is the first jackup that is being 100% built in Kazakhstan, with construction taking place at two docks: Keppel Kazakhstan LLP located at the free economic zone and the final assembly was performed at Ersai Caspian Contractor LLP,"- says Rakimbek Amirzhanov. The Satti rig is designed for drilling operations in the Caspian Sea and its width is 72 meter, the height is 64 meters. The rig consists of modified triangular body with three triangular supports 119 meters high. This will allow drilling as deep as 50 up to 80 meters. The rig has living accommodations and helicopter pad. The total weight of the rig is 10,800 tons.

17 Apr 2015

KrisEnergy completes Rossukon-3 sidetrack well

KrisEnergy Ltd. (“KrisEnergy”), an independent upstream oil and gas company, has announced that the Rossukon-3ST well in G6/48 in the Gulf of Thailand has reached total depth and concludes the company’s 2015 drilling campaign in the area. The Rossukon-3ST well was drilled to a total depth of 2,025 metres and interpreted both oil and gas. The well was drilled by Shelf .... [+ read more] Drilling’s Key Gibraltar jackup rig which will now move to block G10/48 where KrisEnergy will drill the Rayrai-1 exploration well, followed by 15 development wells on the Wassana oil field.

17 Apr 2015

BG comes up dry in North Sea

BG Norge AS, operator of production licence 373 S, is completing drilling of exploration well 34/3-5, located approximately five km southeast of the Knarr Field in the Northern North Sea, around 120 km West of Florø. The objective of well 34/3-5 was to prove petroleum in Early Jurassic reservoir rocks (Cook Formation). Well 34/3-5 encountered a gross Cook Formation interval .... [+ read more] of approximately 82m, of which 47m were good reservoir quality with traces of residual hydrocarbons interpreted. Extensive data acquisition and sampling has been carried out. The well is classified as dry. The well was the seventh exploration and appraisal well in production licence 373 S, which was awarded in APA 2005. The well was drilled to a total vertical depth of 4,253m below the sea surface (4,275m measured depth), and terminated in the Lower Jurassic Amundsen Formation. The water depth is 403 m. The well will now be permanently plugged and abandoned. The 34/3-5 well was drilled by the Transocean Searcher semi-submersible rig. The rig will be left in Kristiansund for approximately 2 months prior to commencing opeations in the North Sea where it will move on to drill well 2/11-11 in production license 616 where Edison Norge AS is the operator.

17 Apr 2015

OMV given approval to spud Wisting prospect

The Norwegian Petroleum Directorate has granted OMV Norge AS a drilling permit for well 7324/8-2, cf. Section 8 of the Resource Management Regulations. Well 7324/8-2 will be drilled from the Leiv Eriksson drilling facility at position 73 24` 0.63" north and 24 26´ 43.60" east. The drilling programme for well 7324/8-2 relates to the drilling of a wildcat well in .... [+ read more] production licence 537. OMV Norge AS is the operator with an ownership interest of 25 per cent and the licensees are Idemitsu Petroleum Norge AS with 20 per cent, Petoro AS with 20 per cent, Tullow Oil Norge AS with 20 per cent and Statoil Petroleum AS with 15 per cent. The production licence consists of blocks 7324/7 and 7324/8. The production licence was awarded in the 20th licensing round in 2009. Wildcat well 7324/8-2 is the fourth exploration well in production licence 537. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

17 Apr 2015

Chevron cuts 'Atwood Osprey' contract by one year

Atwood Oceanics, Inc. (“Atwood”) has announced that the company has entered into an amendment to its contract for its semisubmersible drilling unit, the Atwood Osprey. As previously disclosed, the Atwood Osprey parted several mooring lines and drifted approximately three nautical miles from its original position during Cyclone Olwyn, which impacted the northwest coast of Australia on March 12th, 2015. .... [+ read more] The duration of the force majeure event and resultant repairs necessitated by the damage incurred from the cyclone have triggered termination rights in relation to which the parties have agreed to a reduction in the term of the contract by one year with contractual rates remaining unchanged. It is expected that repairs for damage sustained by the rig and required regulatory approvals will be completed by April 30, 2015.

17 Apr 2015

Rosneft and NADL delay proposed agreement by two years

On August 22nd, 2014 North Atlantic Drilling Ltd. ("NADL") announced that it had entered into a Framework Agreement between NADL, Seadrill and Rosneft Oil Company ("Rosneft"). On November 7th, 2014, the closing of the transaction was delayed until the end of May 2015. Today, all parties have mutually agreed to extend the termination date of the Framework Agreement until May .... [+ read more] 31st, 2017, whereby any party can terminate the Framework Agreement and / or any offshore drilling contracts at any time prior to May 31st, 2017 at no cost. Additionally, the parties have agreed to use reasonable efforts to renegotiate the terms and characteristics of the transactions contemplated in the Framework Agreement and the terms of the related offshore drilling contracts. During this time, NADL is permitted to market the offshore drilling rigs subject to existing drilling contracts with Rosneft and enter into binding contracts with third parties. NADL will also be permitted to delay the construction, delivery, or shipyard stay of any of those rigs. This delay follows the decision to cancel the contracts for the ‘West Navigator’ drillship and ‘Energy Endeavour’ jackup, both of which were also due to go on contract with Rosneft in Russia.

15 Apr 2015

Saudi Aramco reduces wave of jackup rates

Both Ensco Plc. (“Ensco”) and Rowan Companies Plc. (“Rowan”) have announced agreements with Saudi Aramco to reduce dayrates for a combined 12 jackups (five Rowan jackups and seven Ensco jackups). The wave of rate reductions for Rowan’s five units began on the 1st March 2015 and will last 12 months until 1st March 2016. Meanwhile the reductions for Ensco’s began in .... [+ read more] April 2015 and run until January 2016. Rates have been reduced from 9% up to 32% in some cases for the 12 jackups. The announcement of rate reductions for these units is expected to be echoed by other rig managers that have units on contract with Saudi Aramco.

15 Apr 2015

PSA carries out audit of 'Rowan Norway' jackup

From 27th January to 5th February 2015, the Petroleum Safety Authority (“PSA”) Norway carried out an audit of Rowan Norway Ltd's management of major accident risk and systems for barrier management on Rowan Gorilla VI (“RGVI”). The objective of the audit was to monitor that Rowan has implemented a system to fulfil the regulatory requirements for risk management. The audit resulted .... [+ read more] in that non-conformities were identified in connection with; maintenance systems, personnel training, MOB boat preparedness, governing documentation and choke valve. In addition, improvement points were identified in connection with; emergency preparedness analysis, system for performing and following up drills, securing of equipment, system for ensuring competence of new personnel, competence requirements for performance of work operations, response team routines, valves in the drilling fluid system and air cylinders for smoke divers.

14 Apr 2015

Vaalco announces first production from Etame 12-H well

VAALCO Energy, Inc. (“Vaalco”) today announced first production from Etame 12-H, a development well drilled from the Etame platform offshore Gabon. Etame 12-H was drilled to a measured depth of approximately 3,450 meters targeting the recently discovered, untapped lower lobe of the Gamba reservoir. Following completion operations, the well was brought online at the rate of approximately 2,000 BOPD .... [+ read more] on a gross basis (approximately 500 BOPD net to VAALCO) with no indication of hydrogen sulfide (H2S). The well is currently being temporarily constrained at the above production level while it is being optimized for efficiency. The Etame 12-H is an offset well to the Etame 10-H well which began producing in February 2015, at a rate of 3,000 BOPD, and was the first oil production from the recently commissioned Etame platform. "The offshore Gabon drilling campaign that we began last year has so far resulted in increased production of approximately 5,000 gross barrels per day of sweet crude," said Steve Guidry, CEO of VAALCO. "We are pleased with the encouraging results from the Etame 12-H well, and are optimistic about the opportunities we have to expand production offshore Gabon as part of our ongoing development campaign." The contracted jack up rig, the Transocean "Constellation II", is now being mobilized to drill additional development wells from the Southeast Etame/N. Tchibala ("SEENT") platform, beginning with the 2-H well in the Southeast Etame field, where the Company and its partners drilled a successful exploration well in 2010. Following the drilling of the Southeast Etame 2-H well, the rig will drill the North Tchibala 1-H well, the first of VAALCO's wells offshore Gabon to be drilled targeting the Dentale formation. No H2S is expected from the Southeast Etame/N. Tchibala fields.

14 Apr 2015

KrisEnergy announces discovery at Rossukon-3

KrisEnergy Ltd. (“KrisEnergy”), an independent upstream oil and gas company, provides an update on the Rossukon-3 exploration well in G6/48 in the Gulf of Thailand, which was drilled by the Key Gibraltar jack-up rig following the successful evaluation of the Rossukon-2 and sidetrack wells in March 2015. Rossukon-3 was drilled to a total depth of 7,497 feet (2,285 metres) measured depth, .... [+ read more] or -6,235 feet true vertical depth subsea (“TVDSS”). KrisEnergy’s preliminary interpretation of well logs indicates that the well intersected approximately 75 feet true vertical depth (“TVD”) of net oil-bearing sandstones and 49 feet TVD of net gas-bearing sandstones over several reservoir intervals. Water depth at the Rossukon-3 location is 208 feet. The well lies 1.9 km west of the Rossukon-2 surface location and 1.8 km northwest of the original Rossukon-1 discovery well, drilled in 2009. Rossukon-3 will be plugged back and the G6/48 partners have agreed to immediately begin drilling the Rossukon-3ST sidetrack exploration well. Rossukon-3ST is planned to drill to a total depth of 6,689 feet (2,039 metres) measured depth (-4,500 feet TVDSS) at a maximum deviation of 74 degrees. Chris Gibson-Robinson, Director Exploration & Production, commented: “The three wells drilled so far in this campaign are promising and will increase the contingent resources in G6/48. Once Rossukon-3ST is completed, we will undertake a thorough technical review incorporating data from all the Rossukon wells, and the existing seismic data, to more fully assess the potential for commercial development in the future.” G6/48 covers 566 sq. km over the Karawake Basin and lies to the north of the G10/48 licence, where KrisEnergy is developing the Wassana oil field. KrisEnergy took over operatorship of G6/48 in May 2014. The Company holds a 30% working interest in the concession and is partnered by Northern Gulf Petroleum Pte Ltd with 40% and Mubadala Petroleum with 30%. The Key Gibraltar jack-up rig is owned by Shelf Drilling (Southeast Asia) Limited. KrisEnergy contracted the rig for a firm six months for its Thai drilling program, which includes the latest Rossukon series of wells in G6/48 and 15 development wells in the Wassana oil field.

13 Apr 2015

Statoil makes minor gas discovery near Aasta Hansteen

Statoil Petroleum AS, operator of production licence 602, is in the process of concluding the drilling of wildcat well 6706/12-3. The well proved gas. The well was drilled about 12 kilometres west of the Aasta Hansteen field in the northern part of the Norwegian Sea. The objective of the well was to prove petroleum in Upper Cretaceous reservoir rocks, with .... [+ read more] a primary exploration target in the Nise formation and a secondary exploration target in the Kvitnos formation. The well encountered a total gas column of 38 metres in the Nise formation, of which about 30 metres in sandstone of extremely good reservoir quality. In the Kvitnos formation, the well encountered aquiferous sandstone, of which about 35 metres with good reservoir quality. Preliminary estimates of the size of the discovery are between 2-7 billion standard cubic metres (Sm³) of recoverable gas. The well was not formation-tested, but extensive data acquisition and sampling have been carried out. The licensees will evaluate the discovery along with other discoveries, as regards a tie-in to the Aasta Hansteen field. This is the first exploration well in production licence 602, which was awarded in the 21st licensing round in 2011. Well 6706/12-3 was drilled to a vertical depth of 3296 metres below the sea surface, and was terminated in the Kvitnos formation in the Upper Cretaceous. Water depth at the site is 1287 metres. The well will now be permanently plugged and abandoned. Well 6706/12-3 was drilled by the Transocean Spitsbergen drilling facility, which will now permanently plug 34/11-2 S near the Gullfaks field in the North Sea, where Statoil Petroleum AS is the operator.

13 Apr 2015

Falkland Oil and Gas Limited announces change to drilling programme

Falkland Oil and Gas Limited ("FOGL"), the exploration company focused on its extensive licence areas to the North, South and East of the Falkland Islands, has announced that Noble Energy ("Noble") and its joint venture partners FOGL and Edison International ("Edison") have elected to defer a potential second well in the South and East Falkland basin. The joint venture partners have .... [+ read more] concluded; having taken into account a number of factors, that the optimum course of action is to defer the drilling of a second well in the southern basin. In these circumstances FOGL was amenable to a proposal from Noble, that in order to fulfil the drilling commitment, they should utilise the contracted drilling slot to drill a well in the North Falklands Basin. Noble, Edison and FOGL remain fully committed to exploration in the South and East basin and still firmly believe in its prospectivity. The well on the Humpback prospect is considered by the joint venture partners to be the prime 'play opening' well. It is an important test of concept, in terms of evaluating the Cretaceous deepwater fan play and the presence of oil within the Fitzroy sub-basin. Humpback is located near a cluster of similar prospects totalling over one billion barrels of oil. The operator estimates that the Humpback prospect contains between 250 and 650 mmbbls of gross prospective resources (un-risked). If the initial drilling results are encouraging, the joint venture partners will look to fully appraise Humpback and drill other similar prospects within the play area. Such further exploration and appraisal drilling would be part of a future campaign, with wells on either Scharnhorst and/or Starfish also possibly forming part of such a programme. This decision does not impact any existing agreements between FOGL and Noble. In the event that another exploration well is drilled after Humpback, within the joint venture's licence area, FOGL would still retain a partial carry of the drilling costs under the terms of the Noble farm out agreement. FOGL is fully funded for the firm four wells and will be left in a stronger and more sustainable financial position as a result of this decision. Following this agreement, the revised drilling schedule is 1. Zebedee, 2. Isobel Deep, 3. Humpback, 4. Jayne East, 5. Chatham, 6. Rhea. The drilling program is currently being carried out by the Eirik Raude semisub which recently spudded the Isobel Deep well.

13 Apr 2015

Talisman spuds Snomus prospect in Norway

Fortis Petroleum Norway AS (“Fortis”) has announced the successful spudding of exploration well 15/12-24 S. Fortis was informed of the spudding by Talisman Energy Norge AS (“Talisman”), the operator, that the Maersk Giant jackup rig spudded the exploration well on the 13th April 2015. The well is designed to test the hydrocarbon potential of the Snomus prospect in PL 672. Drilling .... [+ read more] is expected to take approximately 67 days.

13 Apr 2015

Karoon hits potential oil and gas at Echidna-1

Karoon Gas Australia Ltd (“Karoon”) has announced that the Echidna-1 well, has intersected an oil bearing section in Paleocene sands as shown on mudlog and logging while drilling data. The mudlog shows elevated gas readings and oil florescence in sandstones. The Echidna-1 well reached its total depth on 12th April 2015 at 2,379mRT, following its spud on the 31st March 2015. .... [+ read more] Karoon is now proceeding with wireline logging to ascertain the extent of the gross and net columns.

10 Apr 2015

Det Norske given approval to drill appraisal well on Ivar Aasen

The Norwegian Petroleum Directorate granted Det norske oljeselskap AS a drilling permit for well 16/1-22 S, cf. Section 8 of the Resource Management Regulations. Well 16/1-22 S will be drilled from the Maersk Interceptor drilling facility at position 58°54’23.1’’ north 02°09’43.2’’ east in production licence 001 B, after completing the drilling of appraisal wells 16/1-21 S and 16/1-21 A. The .... [+ read more] drilling programme for well 16/1-22 S relates to the drilling of an appraisal well on the Ivar Aasen field, where Det norske is the operator with an ownership interest of 34.7862 per cent. The other licensees are Statoil Petroleum AS with 41.4730 per cent, Bayerngas Norge AS with 12.3173 per cent, Wintershall Norge AS with 6.4615 per cent, VNG Norge AS with 3.0230 per cent, Lundin Norway AS with 1.3850 per cent and OMV (Norge) AS with 0.5540 per cent. The area in this licence consists of part of block 16/1. The well was drilled in the south-western part of the Ivar Aasen field in the central part of the North Sea. On 1 September 1999, production licence 001 B was carved out of production licence 001, which was awarded on 1 September 1965 (Round 1-A). This is the seventh exploration well to be drilled within the licence area and the ninth on the Ivar Aasen field. The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to commencing drilling activities.

10 Apr 2015

Total makes minor gas discovery near Skirne field

Total E&P Norge AS, operator of production licence 627, is about to complete the drilling of wildcat well 25/6-5 S. The well was drilled about 7 kilometres east of the Skirne field in the central part of the North Sea, and about 170 kilometres northwest of Stavanger. The objective of well 25/6-5 S was to prove petroleum in Middle Jurassic .... [+ read more] reservoir rocks (Hugin formation). The well encountered a 10-metre gas column in the Hugin formation with good to very good reservoir quality. The well was not formation tested, but data acquisition was carried out. Preliminary calculations of the size of the discovery are between 0.4 and 1.5 million standard cubic metres (Sm3) of recoverable oil equivalents (o.e.). The licensees will evaluate the discovery with regard to development. This is the first exploration well in production licence 627, which was awarded in APA 2011. The well was drilled to a measured and vertical depth of 2520 and 2366 metres beneath the sea surface, respectively, and was terminated in the Dunlin formation in the Lower Jurassic. Water depth is 120 metres. The well will now be permanently plugged and abandoned. Well 25/6-5 S was drilled by the Leiv Eiriksson drilling facility which will now proceed to the Barents Sea to drill wildcat well 7324/8-2 in production licence 537, where OMV (Norge) AS is the operator.

10 Apr 2015

Talisman given green light to spud exploration well 15/12-24 S

The Norwegian Petroleum Directorate granted Talisman Energy Norge AS a drilling permit for well 15/12-24 S, cf. Section 8 of the Resource Management Regulations. Well 15/12-24 S will be drilled from the Maersk Giant drilling facility at position 58°07’26.79’’ north 01°55’22.64’’ east, just northeast of the Varg field in the central part of the North Sea. The drilling programme for .... [+ read more] well 15/12-24 S relates to the drilling of a wildcat well in production licence 672, where Talisman Energy Norge AS is the operator. The other licensees are Ithaca Petroleum Norge AS, Det norske oljeselskap ASA and Fortis Petroleum Norway AS. The licensees, including the operator, all have an ownership interest of