Yavuz (Turkish Petroleum Corporation (TPAO)) (Drillship)

Galoc-7ST-1 Drilling Results

Return to news list

01 May 2017

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

Source: http://www.nido.com.au/irm/PDF/2583_0/DrillingResultsGaloc7ST1


More News for Operator: Turkish Petroleum Corporation (TPAO)

4 Jun 2014

'Deepsea Metro I' drills gas discovery with Taachui-1 well

Ophir Energy plc (Ophir) has announced the successful results of the Taachui-1 & subsequent Taachui-1 ST1 well in Block 1, Tanzania which has resulted in a new gas discovery. Ophir holds 20% of Blocks 1, 3 and 4. BG Group operates with 60%. The Taachui-1 well was drilled by the ‘Deepsea Metro I’ drillship close to the western boundary of Block 1. The well was sidetracked for operational reasons to complete as the Taachui-1 ST1 well and was drilled to a Total Depth of 4215mMD. The well encountered gas in a single gross column of 289m within the targeted Cretaceous reservoir interval. Net pay totalled 155m. Observed reservoir properties are in-line with those encountered at Mzia, the other Cretaceous-aged discovery on Block 1. Estimates for the mean recoverable resource from the discovery are c.1.0 TCF. The size of the gas column is such that the discovery could extend into a second compartment to the west which has the potential to be of a similar size. An appraisal well will be required to confirm this upside and is under consideration by the JV partners. A Drill Stem Test will now be performed on the Taachui discovery with results expected before the end of June.

17 Jun 2014

Sunbird-1 well confirms oil offshore Kenya

Pancontinental Oil and Gas NL (PCL) is pleased to advise that, after lengthy analysis, it has been verified that the recently completed Sunbird-1 well off the southern Kenyan coast has intersected an oil column – the first-ever oil discovered off the East African coast. The Sunbird-1 well was successfully drilled using the ‘Deepsea Metro 1’ drillship. The gross oil column is assessed to be 14m thick beneath a gross gas column of 29.6m in a reefal limestone reservoir in the Sunbird Miocene Pinnacle Reef in area L10A. The corresponding net values are 9.2m for the oil zone and 28.3 m for the gas zone. The net values are calculated for the reservoir using cut-offs of 10% porosity (Phi) and 50% shale volume (Vsh). Oil and gas samples have been recovered and analysed using sophisticated geochemical techniques. The Sunbird Reef is an ancient Miocene pinnacle reef buried beneath approximately 900m of younger sediment. Pancontinental believes the results are highly significant because they are the first proof of the presence a prospective oil system in the Lamu Basin offshore Kenya. The oil and gas have been geochemically typed in detail and the prospective source rocks have been dated and characterised for use in future exploration. Analysis of the Sunbird results has been complicated by the loss of drilling mud, seawater and remedial cement pumped into the limestone reservoir during drilling operations. Pancontinental has an 18.75 percent interest in the well and block L10A. Pancontinental has three extensive exploration areas in this highly prospective Basin covering a total area of approximately 15,000 sq km, including L10A. The detailed oil and gas geochemical data, which are confidential to the L10A Joint Venture partners, give the age and type of the oil source rocks, as well as other crucial data that Pancontinental believes places the L10A Joint Venture in a leading position to find commercial oil offshore Kenya. The Operator of the Block L10A Petroleum Sharing Contract, BG Group, is continuing to analyse the well data and will recommend a future exploration programme using the well results. Pancontinental’s Chief Executive Officer Barry Rushworth said the implications of the Sunbird-1 well results for regional oil exploration were truly outstanding. “The Sunbird-1 oil is the historic first-ever oil discovery offshore Kenya,” Mr Rushworth said.

6 Jan 2014

'Deepsea Metro I' spuds sunbird-1 well in Keya

Pancontinental Oil & Gas NL (PCL) is pleased to advise that the exploration well Sunbird-1 has commenced drilling in Licence area L10A offshore Kenya. The well is managed by the L10A Joint Venture operator BG Group, using the drillship ‘Deepsea Metro 1’. The Sunbird-1 well is planned to take 50 to 60 days to drill to 3,000m below sea level, with an option to extend to 3,700m. Extensive wireline logging and both pressure and fluid sampling are planned. The Joint Venture intends to plug and abandon the well in accordance with normal good oilfield practice regardless of the drilling outcome, however it is planned to leave the well in a condition that would allow re-entry at a later date. Water depth is 721m. Sunbird-1 is the first-ever test of a Miocene Pinnacle Reef offshore East Africa and the first-ever exploration well in L10A in the Lamu Basin offshore Kenya. An extensive trend of Miocene Reefs is evident in Pancontinental’s four licence areas offshore southern Kenya. Sunbird-1 is regarded as a “tight hole” exploration well and results will be announced after completion of the drilling and assessment and integration of the gathered data.

17 Mar 2014

Sunbird-1 drilling is completed by 'Deepsea Metro I'

Pancontinental Oil and Gas NL (Pancontinental) is pleased to provide an update regarding the Sunbird-1 exploration well in area L10A (Pancontinental 18.75%) offshore southern Kenya. As advised in Pancontinental's ASX release on 6th January 2014, Pancontinental was not intending to provide any information concerning the progress of the drilling of the Sunbird-1 well until the well had been completed and it was in a position to provide information that was not considered speculative or incomplete. However, due to the news media reports over the weekend stating that the Sunbird-1 exploration well had discovered oil and natural gas, Pancontinental provides the following clarification: Sunbird-1 Drilling The Sunbird-1 well operated by BG Group (Operator), using the drillship ‘Deepsea Metro-1’, has reached a final depth of 2,850 metres below the drill floor. The water depth is 723 metres. The top of the Sunbird Miocene Pinnacle Reef was penetrated at 1,583.7 metres subsea. The Sunbird Miocene Reef has been found to contain a hydrocarbon column, however the vertical extent of the hydrocarbon column has not yet been determined due to the difficulty of assessing wireline logs in the upper section of the reef where there were extensive losses of drilling fluid into highly porous and permeable parts of the reservoir. Hydrocarbon samples have been recovered for detailed analyses. The full nature of the hydrocarbons will not be known until geochemical and other analyses have been completed. At this early stage of results interpretation, the Operator has advised Pancontinental that it is not yet in a position to properly and fully estimate the vertical extent of the hydrocarbon column, the potential volumes of hydrocarbons, or to provide an accurate assessment of the nature of the hydrocarbons; nor is it in a position to comment on whether the volumes of hydrocarbons discovered appear to be commercial or sub-commercial. Recent and current activities include wireline logging, formation and fluid sampling and preparations for completing the well. It is intended that Sunbird-1 will be “plugged and abandoned” in accordance with the planned drilling programme and industry best practice, meaning that the well will be made safe in such a way that it can be left permanently without further intervention. These measures are designed to ensure that there is no leakage of hydrocarbons within the well, or to the sea floor. Pancontinental will provide further information regarding the well results and a forward work programme when the fully assessed results have been provided by the Operator in the coming weeks.

2 Aug 2012

Ophir strikes gas with Papa-1 well

Ophir Energy plc (Ophir) announces that the Papa-1 well has made the first Cretaceous gas discovery outboard of the Rufiji Delta in Block 3, offshore Tanzania and is the sixth consecutive discovery by Ophir offshore Tanzania. Papa-1 is located ca. 100km in Block 3, offshore Tanzania; 53km south east of the earlier Pweza-1 discovery. The well spudded on 29th May 2012 in 2,186m of water and was drilled by the drillship ‘Deep Sea Metro 1’ to a total depth of 5,544m subsea in 57 days. Papa-1 represents the first exploration test of Upper Cretaceous Intraslope play outboard of the Rufiji Delta and the first well to be drilled in Block 3. The well was designed to evaluate sandstones of Campanian and Albian age within the structural Papa prospect. Papa-1 encountered an 89m gas bearing column in interbedded, Campanian sandstones. Ophir management's preliminary analysis of the discovery suggests an in place resource of 0.5 - 2.0 TCF. Further detailed petrophysical and core analysis will commence shortly to calibrate the logging data and refine the in place and recoverable resource estimates. The Papa discovery further de-risks the deeper, Upper Cretaceous Intraslope play in Tanzania. Additional resources have now been discovered in the Cretaceous stratigraphy outboard of both the Rovuma and Rufiji Deltas by the Mzia-1 and Papa-1 wells. An update of the in place and recoverable resource estimates from the Mzia and Papa discoveries on the new Cretaceous Intraslope play will follow the ongoing petrophysical analysis. The BG-Ophir Joint Venture's first four discoveries have successfully tested targets of Miocene, Oligocene and Paleocene age in the Tertiary Intraslope Play and are currently estimated to have discovered total recoverable resources of ca. 7 TCF (1167 MMBOE). The fifth discovery, Mzia, and the sixth discovery, Papa, both in the new Upper Cretaceous Intraslope Play are expected to add considerable additional recoverable resource to this total. The ‘Deep Sea Metro 1’ drillship will now be sub-let to Apache for a single well in Block L8, Kenya, adjacent to Ophir's Block L9 (60%), before returning to continue operations with the Ophir-BG Joint Venture in Tanzania. The Joint Venture will recommence drilling in Block 1, Tanzania in October 2012. Next in the sequence will be two step-out exploration and appraisal wells around the 3.4 TCF (567 MMBOE) Jodari discovery for a potential hub for the LNG development in Block 1.

21 Nov 2014

Ophir comes up dry at Tende-1

Ophir Energy plc announces an operational update on recent drilling in Tanzania. The Tende-1 well was drilled in East Pande by the ‘Deepsea Metro I’ drillship in a water depth of 781m to a total depth of 4,153m targeting the Cretaceous-aged Tende prospect. Although gas traces were encountered in the upper strata of the primary objective, wireline logs confirmed that no moveable hydrocarbons were present in this prospect. In the secondary Tikiti objective, the Tende-1 well encountered a gas bearing sandstone. The Company will evaluate the wider impact of this find as it integrates the well results into its understanding of the remaining prospects in the East Pande block. Following the Tende-1 well, the ‘Deepsea Metro I’ drillship moved to Block 7 where the Mkuki-1 well was drilled to a total depth of 3,204m. The well targeted a Tertiary-aged stratigraphic prospect located in water depths of 1,648m and encountered a high quality sandstone sequence, but no hydrocarbons were present.

16 May 2015

VietGazprom contracts 'Deepsea Metro I'

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

2 May 2017

Deepsea Metro I to Demobilise from Galoc Well

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

16 May 2012

Mzia-1 Gas Discovery - Block 1 Offshore Tanzania

Ophir Energy plc ("Ophir" or "the Company") is pleased to announce its fifth consecutive gas discovery offshore Tanzania. The Mzia-1 well in Block 1 intersected a 178m gas bearing column and 55m of net pay in the Upper Cretaceous. Mean in place resource is estimated at 3.5 TCF, with significant potential upside. Further technical work will determine the recoverable resource of this substantial, commercial gas discovery. Mzia-1 was the first Ophir-BG JV well to solely target the Upper Cretaceous of the Rovuma Delta and tested stacked reservoir intervals. The well was located 45km off the coast of Tanzania and 45km north of the Mozambique maritime border, spudded in 1,639m of water and drilled to a total depth of 4858m subsea. Two stacked reservoir intervals were intersected with gas columns of 55m and 123m respectively. Total net pay was 55m and no gas water contacts were observed. An additional, shallower potential reservoir interval was observed but not intersected at this location; this interval has been de-risked by the Mzia-1 result and offers upside potential. Total low case, mean and high case in place resources for the Mzia-1 discovery are estimated at 2.0 - 3.5 - 6.0 TCF respectively. As this is the first well calibration point in the Cretaceous, further technical work will now be undertaken to determine the recoverable resource volumes of this substantial, commercial discovery. Mzia was the fifth well to be drilled by the Ophir-BG joint venture offshore Tanzania. Prior to Mzia-1, the first four wells had discovered total mean recoverable resources of 7 TCF. The Mzia-1 result will add substantially to this total. Ophir holds 40% of Blocks 1, 3 and 4; BG operates the Blocks with 60%. The Metro 1 drillship will now move north to Block 3 to drill the Papa-1 well, a test of the equivalent Upper Cretaceous section in the Rufiji Delta. Papa-1 has a pre-drill mean estimated prospective resource of 3.1 TCF and a 40% chance of success. Results from the Papa-1 well are expected in July 2012. Separately, the 3D seismic acquisition programme to explore a potential continuation of Tertiary basin floor fan prospectivity from Mozambique into the eastern portion of Block 1 is nearing completion, with preliminary processing, mapping and interpretation expected by Q3 2012.

26 Mar 2012

Result of Jodari-1 well in block 1 offshore Tanzania

Jodari-1 was designed as a play-finder well to test slope-channel targets of Miocene, Lower Tertiary and Upper Cretaceous age. Log analysis shows that the well intersected the edge of a Miocene accumulation and two intervals of Lower Tertiary age, with 113m and 11m of gross pay respectively and high quality reservoirs. The Upper Cretaceous encountered formation gas but was not considered pay at this location. The significantly greater aggregate pay thickness and excellent net to gross ratio have substantially exceeded pre-drill expectations and result in the 3.4 TCF mean recoverable resource estimate. The well was spudded on 7th January 2012 in 1153m of water and was drilled by the drillship "Deep Sea Metro 1" to a total depth of 4465m subsea in 73 days. The Metro-1 drillship will now return to Mzia-1 (where the top hole section was drilled in early January prior to commencing Jodari-1) in order to complete the bottom portion of the well. The Mzia-1 well is estimated to take 75 days to drill and is targeting a 4.6 TCF Upper Cretaceous prospect with a different seismic anomaly to that calibrated by the Jodari-1 well. Jodari-1 was the fourth well to be drilled by the Ophir-BG joint venture in their jointly held acreage and was the first well to be operated by BG. Ophir holds 40% of Blocks 1, 3 and 4; BG operates with 60%.

27 Mar 2014

Ophir releases Taachui well update

The Taachui well is being drilled by the Deepsea Metro 1 drillship on a prospect on the north-west margin of Block 1, Tanzania. It is targeting gross mean pre-drill recoverable resource estimates of 1.4 TCF in reservoirs of Cretaceous age. The well commenced operations on 24 March 2014 and has a planned Total Depth of approximately 4,050m TVDSS. It is expected to take approximately 55 days to complete. Ophir has a 20% non-operated interest in Block 1 operated by BG Group.

Return to news list