Infield Rigs News

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

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.

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.

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

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.

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.

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.