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KBR Wins Tanzania LNG Contract

KBR announced that it was awarded a contract by Statoil Tanzania AS to perform pre-front end engineering and design (pre-FEED) studies for a prospective liquefied natural gas facility in Tanzania, East Africa.

The pre-FEED study is designed to help Statoil further assess the viability of developing an LNG facility to export natural gas from this East African region. The project is expected to be completed during 2013.

“We are excited to be selected by Statoil for this important project,” said Mitch Dauzat, president, Gas Monetization. “KBR looks forward to working together with Statoil to define their LNG concept for Tanzania.”

KBR has been working with Statoil for more than 30 years and has an outstanding record for successful project execution, predominantly for Statoil’s Gas Processing plants.

KBR Wins Tanzania LNG Contract LNG World News.

Wood Mackenzie: East Africa’s Yet-to-Find Reserves Hold 95 tcf of Gas

Wood Mackenzie: East Africa’s Yet-to-Find Reserves Hold 95 tcf of Gas| Offshore Energy Today

Wood Mackenzie estimates that 100 trillion cubic feet (tcf) of gas has been discovered in Mozambique and Tanzania to date, ranking the Rovuma Basin as one of the most prolific conventional gas plays in the world.

However, there are significant technical and commercial challenges to be overcome in order to bring the gas to market by the end of this decade. These include: addressing issues around infrastructure, government capacity, financing and reaching a positive outcome to unitisation negotiations in Mozambique.

Recent discoveries and high profile M&A activity in Mozambique and Tanzania are attracting attention and Martin Kelly, Wood Mackenzie’s Head of Sub-Sahara Upstream Research, says the interest is justified: “100 tcf of gas has been discovered to date in East Africa and we estimate yet-to-find reserves could be as much as 80 tcf in Mozambique and 15 tcf in Tanzania. There is clearly plenty of gas to supply the likely commercialisation route of LNG – theoretically enough to support up to 16 LNG trains.

“The Rovuma basin is the most prolific in the region, and one of the hottest conventional gas plays in the world, with 85 tcf discovered so far. Globally in 2011, it yielded the third most hydrocarbons, and we expect it to top the list in 2012 if the first half of the year is anything to go by,” Kelly continues.

In neighbouring Tanzania, the targets are the northern extension of the Rovuma Basin and the Mafia Basin. Kelly says: “Tanzania has enjoyed considerable exploration success as well, but hasn’t discovered the same scale of reserves. The average discovery size is much smaller at around 2 tcf, compared to Mozambique which is over 7 tcf. Discoveries in Tanzania are also more spread out, so developing them will be more expensive than those in Mozambique because additional infrastructure will be required.”

One of the most immediate challenges for Mozambique, is the unitisation discussions which Wood Mackenzie understands have already begun. Kelly explains; “Of the 85 tcf of gas discovered to date in Mozambique, around half of it is thought to be one enormous field which is in communication across the block. Under Mozambican law, a unitisation agreement between the operating parties will be required.”

Although there is a risk that unitisation discussions could delay Final Investment Decision (FID) – the crucial last step before commercial development – and therefore LNG production, there are other discoveries which are wholly contained in Area 1 and Area 4 and therefore gas could come from these first.

Giles Farrer, Senior LNG research analyst for Wood Mackenzie comments: “Many challenges will need to be overcome prior to LNG project sanction. The region’s remoteness and lack of development present serious technical obstacles. There is virtually no existing skilled workforce and both Mozambique and Tanzania will have to build and establish deepwater ports capable of servicing the needs of the petroleum sector. On the commercial side, there is the question of government capacity – whether there is sufficient impetus and capability within the governments and national oil companies to advance the huge legislative, bureaucratic, customs and financial challenges that such a development would bring.

“The major outstanding milestone for Mozambique is the conclusion of a commercial framework agreement, which is in the process of being negotiated. It will determine how the LNG facility or facilities will be structured for the purpose of taxation and whether the Joint Ventures (JVs) will co-operate in the construction of a single, mega LNG facility, or pursue individual developments. One crucial advantage that the Tanzanian projects enjoy is that they have already negotiated commercial terms, prior to the announcement of their projects.”

Farrer continues: “Lastly there is the question of finance, we estimate that a two train greenfield development in the region is going to cost at least US$25 billion, and for some of the players involved financing their share of this sort of development cost will certainly prove challenging and could delay development.”

The joint analysis by Wood Mackenzie’s upstream and LNG research teams stresses that these challenges are not insurmountable. “They have been encountered and overcome in several countries before. The risk is that delays could lengthen development schedules and add to costs,” Farrer says in closing.

Wood Mackenzie: East Africa’s Yet-to-Find Reserves Hold 95 tcf of Gas| Offshore Energy Today.

5th Discovery in a Row for BG Group Offshore Tanzania

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BG Group today announced its fifth consecutive Tanzania gas discovery with the Mzia-1 exploration well located in Block 1, offshore southern Tanzania.

Mzia-1 is BG Group’s first discovery within the deeper Cretaceous section and opens an extensive new play fairway within the Group’s offshore acreage in Blocks 1, 3 and 4, to complement the now proven Tertiary fairway.

Preliminary evaluation of the results indicates 55 metres of natural gas pay in good quality sands. An extensive logging programme has been completed, including the acquisition of pressure data and gas samples.

Significantly, the well has de-risked a number of adjacent Cretaceous prospects, which could form part of a future Mzia hub. These prospects are expected to be tested in a future appraisal programme to be defined following incorporation of data from this new well and 3D seismic.

The new resources proven by Mzia and the potential of adjacent prospects are currently under evaluation. Prior to drilling Mzia-1, BG Group had estimated mean total gross recoverable resources approaching 7 trillion cubic feet of gas from the four previous discoveries drilled in Tanzania.

Mzia-1 is approximately 45 kilometres offshore southern Tanzania in a water depth of 1 639 metres. It is some 23 kilometres from the Jodari-1 discovery and is part of the 2012 three-to-four well exploration programme.

Following the imminent completion of operations at Mzia, the Deepsea Metro-1 will relocate to Block 3 for the drilling of the next exploration prospect, Papa-1.

BG Group as operator has a 60% interest in Blocks 1, 3 and 4 offshore Tanzania, with Ophir Energy plc holding 40%.

Source

Recap: Worldwide Field Development News (Mar 23 – Mar 29, 2012)

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This week the SubseaIQ team added 2 new projects and updated 35 projects. You can see all the updates made over any time period via the Project Update History search. The latest offshore field development news and activities are listed below for your convenience.

Asia – Caspian
Kashagan Looking to Year-End to Come Online
Mar 26, 2012 – The Kashagan field is continuing to be developed in several phases with the first phase targeting first production by year-end 2012. Kashagan is located 50 miles (80 kilometers) southeast of Atyrau, and is the first large-scale offshore petroleum development in Kazakhstan.
Project Details: Kashagan Project
Australia
Roc Oil Offloads Interest in Taranaki Basin
Mar 23, 2012 – Roc Oil has withdrawn its interest from offshore exploration block PEP 52181, located in the Taranaki Basin, New Zealand. The company said it has been working to farm-down its 50 percent interest in the block to provide a more balanced equity position prior to entering into a commitment to drill an exploration well on the Kaheru prospect. “The decision to withdraw from the permit was based on the need for ROC to carefully balance expenditure and risk profiles over the coming years, as the Company enters into an intensive period of activity, especially at the Beibu Gulf project, offshore China, and the Balai Cluster Risk Service Contract, offshore Malaysia,” commented Roc’s CEO, Alan Linn in a statement.
Project Details: Kaheru
Africa – Other
BG Group Makes Fourth Gas Discovery in Tanzania
Mar 26, 2012 – BG Group hits gas pay again, offshore Tanzania, making this the fourth discovery in the area. Preliminary evaluation of well results indicate gross recoverable resources are in the range of 2.5 to 4.4 Tcf of gas. The discovery was made in Jodari-1, which is situated in a water depth of 3,770 feet (1,150 meters). The well is part of the current three-to-four well exploration program, which also includes the acquisition of 965 square miles (2,500 square kilometers) of 3D seismic data in Block 1. BG Group will now target the Mzia-1 location in Block 1, about 14 miles (23 kilometers) to the north of Jodari-1.
Project Details: Jodari
Eni Scores Again in Area 4 Offshore Mozambique
Mar 26, 2012 – Eni has made a “giant” natural gas discovery in Area 4 offshore Mozamique at the Mamba North East 1 exploration prospect. The operator said that the results of this well are of special importance since they increase the resource base of Area 4 by at least 10 Tcf of which 8 Tcf of these contained in reservoirs exclusively located in Area 4. This new discovery further improves the potential of the Mamba complex in Area 4 offshore Mozambique, now estimated to hold at least 40 Tcf of gas-in-place. Mamba North East 1 encountered a total of 787 feet (240 meters) of gas pay in multiple high-quality Oligocene and Eocene sands. It proved reservoir continuity and pressure communication with Mamba South 1 and Mamba North 1 wells. During 2012, Eni plans to drill at least another four wells in nearby structures to fully assess the upside potential of the Mamba Complex.
Project Details: Mamba South/North
S. America – Other & Carib.
Total to Appraise Zaedyus Discovery in 2012
Mar 26, 2012 – Total plans to conduct an extensive drilling campaign, in the Guyane Maritime License offshore French Guiana, and a further 3D seismic survey in 2012. The license contains the Zaedyus discovery in a water depth of 6,719 feet (2,048 meters).
Project Details: Zaedyus
Europe – East
Gazprom Conducting Engineering Studies on Shtokman
Mar 26, 2012 – Total announced that engineering studies are underway for the portion of the Shtokman project that will allow the transport of gas by pipeline through the Gazprom network (offshore development, gas pipeline and onshore gas and condensates processing facilities on the Teriberka site) and for the LNG part of the project. This will allow the export of 7.5 Mt/y of LNG from a new harbor located in Teriberka, representing approximately half of the gas produced by the first development phase. Estimated to hold 3.8 Tcm of natural gas and 37 million tons of gas condensate, Shtokman is situated in the central region of the Russian sector of the Barents Sea, about 372 miles (599 kilometers) north of the Kola Peninsula in water depths measuring 1,050 to 1,115 feet (320
Project Details: Shtokman
Europe – North Sea
Operations at North Sea Tartan Platform to Restart Soon
Mar 29, 2012 – Bridge Energy reported that the Tartan and Duart field operator, Talisman, is working to restart operations on the Tartan platform and projects production to restart at the end of March. The extended shutdown on Tartan has enabled completion of a comprehensive work scope which should increase the near term uptime of the facility, said Bridge. The increased host uptime and a period of flush production following the long shut down is expected to partly offset the delayed production volumes.
Technip to Supply Umbilicals for Cheviot Development
Mar 29, 2012 – Technip’s wholly-owned subsidiary Duco received a contract by Bluewater Industries for the Cheviot field development. The contract covers engineering, project management and fabrication of four static steel tube umbilicals, four dynamic thermoplastic umbilicals, and a thermoplastic subsea intervention valve umbilical. The total length is 7.5 miles (12 kilometers). The umbilicals will control four drill centers from a floating semisubmersible production facility. The project is scheduled for delivery in 2014.
Project Details: Cheviot
Total Believes Gas Coming from Rocks above Elgin Reservoir
Mar 29, 2012 – Total may have confirmed the source of the gas leak at its Elgin platform in the Norwegian sector of the North Sea. The firm insists that the still-alight flare on the platform does not pose any immediate risk. After reports early Thursday morning that Total had a “good idea” of the source of the gas leak on its Elgin platform, a spokesperson for the firm told Rigzone: “We believe the hydrocarbons are coming from a rock formation above the reservoir at a depth of 4,000 meters [13,120 feet].” On Wednesday evening, Total released a press statement explaining the situation regarding the flare on the Elgin platform. “The flare is an integral part of the platform’s safety system. In an emergency, it is used to safely evacuate all the gas from the platform. During the incident, it performed this task perfectly, allowing everyone to evacuate safely,” said Total. “The flare is still lit because when the platform is shut down and de-pressurised in an emergency, it cannot be fully purged as done in a controlled shutdown. This is perfectly normal. Some liquids do remain in the system and these liquids are now evaporating. As these liquids evaporate, the flow of hydrocarbons to the flare will exhaust itself and the flare should burn out.”
Project Details: Elgin/Franklin
Sevan Marine to Perform Study of Skrugard/Havis Development
Mar 29, 2012 – Statoil has awarded Sevan Marine a study of the potential application of a Sevan FPSO for the company???s Skrugard/Havis development in the Barents Sea. The study will be performed from April 2012 to May 2013 and will be focused on further development of the Sevan FPSO as basis for future preferred concept.
Project Details: Skrugard
NPD Gives Faroe Approval to Drill Clapton Prospect
Mar 27, 2012 – The Norwegian Petroleum Directorate has granted Faroe Petroleum a drilling permit for wellbore 2/8-18. The well will be drilled from the Maersk Guardian (350??? ILC) jackup in Production License 440 S. Well 2/8-18 S is the first exploration well to be drilled in the production license.
Project Details: Clapton
Aker to Deliver Subsea Connection System for Draugen Project
Mar 27, 2012 – Aker Solutions received a contract from Shell to deliver subsea connection systems for the Draugen field on the Norwegian Continental Shelf. The scope of work includes the delivery of complete tie-in connection systems for production flowlines and umbilicals for the expansion of the Draugen field. Management, engineering and procurement of the connection systems will be performed at Aker Solutions’ head office in Fornebu, Norway. Equipment deliveries will be made from 2012 to 2013.
Project Details: Draugen
Fogelberg Sits Idle as Consortium Mulls Development Options
Mar 27, 2012 – Faroe Petroleum reported that the Fogelberg consortium is mulling development plans for the discovery. The discovery is close to the Asgard production and transportation system but it???s currently at maximum levels and the timing of the Fogelberg project therefore remains uncertain. Oil industry groups have several ongoing initiatives to de-bottleneck the gas export system and bring forward new developments in the area. Discovered in 2010, Fogelberg is estimated to contain approximately 3 to 15 MMcm of recoverable oil equivalent.
Project Details: Fogelberg
Glenlivet Discovery Moving Towards Field Development Plan Submission
Mar 27, 2012 – The partners in the Glenlivet discovery are working to mature the project towards concept selection and Field Development plan submission. The field could become a significant part of the new planned UK west of Shetland gas gathering system, which is being installed by Total as part of the Laggan and Tormore gas field development. Glenlivet is situated approximately 19 miles (31 kilometers) from the proposed Laggan and Tormore gas export pipeline to Sullom Voe in the Shetland Islands. Glenlivet was discovered in 2009 when the well encountered gas pay in the Paleocene sandstone.
Project Details: Glenlivet
Det norske to Commence Development Drilling on Jette Field
Mar 27, 2012 – Det norske received consent to use the Transocean Barents (UDW semisub) to drill the Jette field. A plan for development and operation for Jette was approved in February 2012. Det norske will develop the field with a seabed facility tied into the Jotun field. Jette???s planned production start is during the first quarter of 2013. The water depth of the site is 417 feet (127 meters). Drilling is expected to commence during the second quarter of 2012 and last about 155 days.
Project Details: Jette (Jetta)
Statoil, Det norske Pen Pre-Unit Agreement for Johan Sverdrup Development
Mar 27, 2012 – Statoil and partners have signed a pre-unit agreement regarding the Johan Sverdrup discovery in the Norwegian sector of the North Sea. According to the agreement, the owners of production licenses 265 and 501 will cooperate in the planning of the Johan Sverdrup field towards an investment decision and submission of the Plan for Development and Operation (PDO). Statoil has been appointed as the working operator. The work will form the basis for developing and establishing the best field solution for Johan Sverdrup. An agreement for the development and operational phase will be signed between the licensees ahead of the submission of the PDO to Norway’s Ministry of Petroleum and Energy.
Project Details: Johan Sverdrup
Apache Lines Up Rig to Drill Tryfan Prospect
Mar 27, 2012 – Apache has signed a letter of intent for the Borgsten Dolphin (mid-water semisub) to drill the Tryfan prospect. Tryfan is an Eocene channelized sand play in the UK Northern North Sea which benefits from a strong seismic amplitude response. Tryfan has gross prospective resources estimated internally by Valiant to be 24 MMboe.
Project Details: Tryfan
Valiant Spuds Tybalt Appraisal Well
Mar 27, 2012 – Valiant Petroleum has commenced drilling on the Tybalt appraisal well in the UK sector of the North Sea. The work program, which includes a well and a contingent test, is designed to prove commercially exploitable volumes via a nearby infrastructure which includes the Magnus fields and the Dons Area complex. Tybalt is an Upper Jurassic discovery originally made by Valiant in 2010 with gross resources estimated at Valiant to be 7 MMbbls. The well is being drilled by the Borgsten Dolphin (mid-water semisub) rig and is expected to take 35-40 days to complete.
Project Details: Tybalt
Ithaca Increases Stake in Carna Discovery
Mar 26, 2012 – Ithaca Energy has agreed to take over operatorship and increase its working interest in the Carna discovery, located in the UK sector of the North Sea. The transaction with Centrica North Sea Gas Limited increases the company’s working interest in the Carna discovery to a material level from 16 to 32 percent. Carna straddles Blocks 43/21b and 43/22c in a water depth of 177 feet (54 meters). The discovery was made in early 2009 when a gas column in excess of 1490 feet TVD (true vertical depth) and net pay of 127 feet TVD was encountered in well 43/21b- 5Z. The well tested gas at a gross stabilized rate of 8.8 Mmcf/d on a 48/64th choke from a vertical well penetrating the Carboniferous. The Company has agreed to a work program with all of the Joint Venture partners to accelerate development studies of the Carna discovery and, if appropriate to submit a field development plan for approval to the Department of Energy and Climate Change before the end of 2012.
Project Details: Carna
Total Closes Elgin/Franklin Production
Mar 26, 2012 – Total has shut down oil and gas production at its Elgin/Franklin platform in the North Sea following an ongoing gas leak. The firm confirmed that all 238 personnel on the platform have been accounted for and that an aerial surveillance flight has been scheduled to inspect a sheen reported in the vicinity of the platform. Production started from Elgin in March 2001, and Franklin began producing in August 2001. Peak production for hub facility is 280,000 boepd, or 175,000 bpd of condensate and 547.4 MMcf/d (15.5 MMcm/d) of gas.
Project Details: Elgin/Franklin
Lundin Completes, Tests Johan Sverdrup Appraisal Well
Mar 26, 2012 – Lundin Petroleum announced that the Johan Sverdup appraisal well 16/2-11 encountered a 177-foot (54-meter) gross oil column in Upper and Middle Jurassic sandstone reservoir in an oil-down-to situation. A comprehensive logging and coring program was successfully completed as well as a production test in the previously untested Middle Jurassic reservoir. The data from this first well in the 2012 PL501 appraisal program confirmed good reservoir properties. This is in line with the earlier Johan Sverdup wells where the Upper Jurassic reservoir was of excellent quality with a high net to gross ratio. A full scale production test (DST) in the Middle Jurassic reservoir to investigate its flow properties resulted in flow rates, in excess of 2,700 bopd through a restricted 40/64 choke, with good reservoir properties indicating a lateral continuous reservoir. Lundin will now sidetrack the well towards the east to investigate the lateral thickness and property variations of the Jurassic reservoir as well as establish an oil water contact to investigate the possibility of a deeper oil-water-contact in this area.
Project Details: Johan Sverdrup
BP Spuds North Uist
Mar 26, 2012 – BP has commenced exploratory drilling on the North Uist prospect in the UK sector of the North Sea. The well has several reservoir objectives, the most significant of which is North Uist at the Upper Jurassic level. The well will also test the edge of the Cardhu prospect where sandstones of Paleocene age may be present. The Stena Carron (DW drillship) is drilling the well in 4,236 feet (1,291 meters) of water.
Project Details: North Uist
Statoil Gets Govt Nod to Drill Top Holes on Stjerne Field
Mar 26, 2012 – Statoil received consent to drill top holes in development well 30/9-22 on the Stjerne, formerly Katla, field. The plan for development and operation of Stjerne was approved by the Storting in September 2011. Stjerne was later included in the Oseberg Sor field and will be subsea tied-back to the Oseberg Sor platform. The consent applies to drilling of four top holes on the following wells: 30/9-M-11 H, 30/9-M-12 H, 30/9-M-13 H and 30.9-M-14 H. The water depth of the site is about 338 meters (103 meters).
Project Details: Oseberg Center
Technip Receives Subsea Contract for Quad 204 Project
Mar 26, 2012 – Technip received a contract from BP to develop the subsea infrastructure for the Quad 204 project in the UK sector of the North Sea. The Quad 204 project involves replacing the existing Schiehallion production facility with a new purpose built FPSO and installing extensive new subsea infrastructure. This major redevelopment will enable the potential recovery of an additional 450 million barrels of resource and extend production through 2035. The awarded contract includes the removal of the existing Schiehallion FPSO and mooring system; recovery of all existing flexible risers and dynamic umbilical systems; positioning and installing a new FPSO and associated mooring system and anchor piles; supply and installation of 21 dynamic flexible risers; installation of four static and dynamic umbilicals; coating, welding and installation of 13 steel pipelines, totaling 31 miles (50 kilometers); supply and install numerous flexible jumpers; installation of various manifolds, jumpers and infrastructure associated with the field development. Offshore work is slated to begin in 2013.
Project Details: Schiehallion (Quad 204)
Barryroe Proves to be More than a One-Hit Wonder
Mar 23, 2012 – Providence Resources has further flow tested the Barryroe discovery offshore southern Ireland. After an additional 17-foot thick net gas-bearing section was perforated to test the potential of the upper part of the sandstone section, highly productive flow rates of 7 MMcf/d and 1,350 bopd were measured. Providence added that a preliminary modeling of the pressure data indicates that a co-mingled flow rate of 17 MMcf/d and 3,350 bopd at a flowing well-head pressure of around 500 pounds per square inch is achievable. Well suspension operations are now complete and the GSF Arctic III (mid-water semisub) rig will now be demobilized to the UK.
Project Details: Barryroe
Statoil Hits Oil Pay Near Oseberg
Mar 23, 2012 – Statoil has made a small oil discovery in PL053 production license in the Norwegian sector of the North Sea. The consortium is in the process of concluding drilling operations in exploratory well 30/6-28S. The well, drilled by the COSLPioneer (mid-water semisub), proved an oil column of around 40 feet (12 meters) in the Statfjord formation. The estimated volume of the discovery is in the range of 12 to 18 MMbbl of recoverable oil equivalents. Statoil said the find is located beneath the Oseberg field and is a good candidate to be connected to the Oseberg production facilities. The oil discovery lies in the Crimp prospect, which was the secondary target for exploration well 30/6-28S. The primary target was the Crux prospect that Statoil earlier defined as a high-impact gas opportunity. With the Crux prospect Statoil tested a hypothesis for the existence of a separate gas-filled structure underlying the Oseberg field. However, the Crux prospect did not contain hydrocarbons.
Project Details: Oseberg Center
S. America – Brazil
Waimea, Waikiki to be Declared Commercial in 2012
Mar 23, 2012 – Dow Jones Newswires reported that OGX plans to declare the Waimea and Waikiki offshore oil fields commercial in 2012. The Waimea field, which came online in January, will be commercially declared in the second quarter; and Waikiki will also receive a similar declaration some time this year. The operator plans to submit a development plan for Waimea to Brazil’s National Petroleum Agency, or ANP, in the second quarter. Upon approval, additional wells will be connected to the OSX-1 FPSO. Waimea is currently producing about 12,500 bopd from a single production well, with output expected to reach 40,000 to 50,000 bopd by the end of 2012. Increased output is set to come from two additional production wells that will be connected this year, with engineering studies underway to gauge the feasibility of adding a fourth production well. Furthermore, OGX plans to bring Waikiki online in 2013. The operator stated two FPSOs, OSX-2 and OSX-3, are about 30 percent complete and construction is continuing at a Singapore shipyard.
N. America – US GOM
McMoRan Updates Flow Testing Ops at Davy Jones Well
Mar 29, 2012 – McMoRan is continuing to flow test the Davy Jones No. 1 well on Block 230 at South Marsh Island. As previously reported, McMoRan saw positive pressure response from the Wilcox “D” sand which was perforated on March 24, 2012. On March 26, 2012, the operator attempted to perforate the Wilcox “C” sand. As the perforating gun was being removed from the hole, the well began to flow. When the gun was brought to the surface, it was determined that the gun did not fire in the Wilcox “C” sand from what appears to be a simple disconnection of the detonator cord. The company plans to use a new perforating gun to complete the testing of the Wilcox “C” sand. Currently, the test is ongoing from only the Wilcox “D” sand, which resulted in the flare shown in the exhibit attached. The flow from the “D” sand is being affected by considerable debris in the 5-inch liner, from what McMoRan believes to be residual drilling fluid from drilling of the well. Results of a clean flow test, as opposed to the current test hampered by debris, will be announced as further progress is achieved and flow rates are measurable. McMoRan will provide updates as completion operations progress.
Project Details: Davy Jones
Africa – West
Total Acquires 3D Data Offshore Cote d’Ivoire
Mar 26, 2012 – Total has commenced exploration work on its CI-100 license offshore Cote d’Ivoire. The company acquired 247,105 acres (1,000 square kilometers) of 3D seismic data at the end of 2011, which completed the 3D coverage of the entire block. Initial exploratory drilling is planned for the end of 2011. Spanning more than 494,211 acres (2,000 square kilometers), the CI-100 block is located about 62 miles (100 kilometers) southeast of Abidjan in water depths ranging from 4,921 to 10,171 feet (1,500 to 3,100 meters).
Total Moves Forward with CLOV Development
Mar 26, 2012 – Total reported that the CLOV development is progressing as planned with start-up slated for 2014. The CLOV project is located on Block 17 offshore Angola. Total’s Angolan subsidiary, Total E&P Angola, is the operator of Angolan Block 17 with a 40 percent interest. Partners in the license include Statoil with a 23.33 percent interest, Esso Exploration Angola with a 20 percent interest and BP Exploration Angola with a 16.67 percent interest.
Project Details: CLOV
Total to Further Develop Moho-Bilondo Project
Mar 26, 2012 – Total reported that the drilling of two appraisal wells, Bilondo Marine 2 and 3, drilled at year-end 2010 in the southern portion of the Moho Bilondo field confirmed an additional growth potential as an extension of existing facilities. Studies are underway for the development of these additional reserves. The development of these resources in the northern portion of the field, the potential of which was bolstered by appraisal and exploration wells drilled in 2008 and 2009, is also being examined (Moho North project). The field is currently producing nearly 90,000 bopd from 13 subsea wells tied into a floating production unit. The oil is exported to the onshore Djeno terminal. Total operates the license, holding a 53.5 percent interest; Chevron holds 31.5 percent; and Societe Nationale des Petroles du Congo holds 15 percent.
Project Details: Moho-Bilondo
African Petroleum Contracts Rig for Two-Well Program
Mar 23, 2012 – African Petroleum reported that the Narina-1 well reached a total depth of 15,912 feet (4,850 meters) in a water depth of 3,750 feet (1,143 meters). The well encountered a total of 105 feet (32 meters) net oil pay in two different reservoirs including a Turonian submarine fan and an Albian zone. The prospective size of the Turonian reservoir is 61,776 acres (250 square kilometers) based on 3D seismic interpretation but will need to be confirmed through an upcoming appraisal drilling campaign. The operator has secured the Eirik Raude (UDW semisub) for a two-well program with the option for a third well. Drilling is expected to commence in the second half of 2012.
Project Details: Narina

BG Group makes fourth gas discovery in Tanzania

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by  BG Group
Press Release
Monday, March 26, 2012

BG Group announced Monday a fourth Tanzanian gas discovery from the Jodari-1 exploration well located in Block 1 offshore southern Tanzania. Preliminary evaluation of the well results indicates gross recoverable resources are in the range of 2.5 to 4.4 trillion cubic feet (tcf) of gas.

The partnership of BG Group (60 percent and operator) and Ophir Energy (40 percent) have had exploration successes in all four wells so far drilled in Tanzania, with mean total gross recoverable resources currently estimated to be approaching some 7 tcf of gas.

Jodari-1 is located approximately 24 miles (39 kilometers) offshore southern Tanzania and in a water depth of 3,770 feet (1,150 meters). It is part of the current three-to-four well exploration program, which also includes the acquisition of 965 square miles (2,500 square kilometers) of 3D seismic data in Block 1.

The next target for drilling is the Mzia-1 location in Block 1, some 14 miles (23 kilometers) to the north of Jodari-1. The discoveries announced previously are Chaza-1 in Block 1, and the Chewa-1 and Pweza-1 discoveries in Block 4.

Source

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