CNODC Nigeria has initiated prequalification of contractors to process the 3D seismic data it acquired on the Nigerian Oil Prospecting Lease, OPL 471, in shallow offshore western Niger Delta. The China National Oil Development Corporation (CNODC), a subsidiary of the Chinese state behemoth CNPC, wants a full kirchoff post stack time migration (PSTM)processing for the 1,200sq km survey, which was acquired in 15-45metre water depth at bin size of 12.5 x 25 and a 60 fold coverage. The company says record length is nine seconds(in time depth). CNODC won OPL 471 in a bid round in 2006 and signed a Production Sharing Contract with the state hydrocarbon company NNPC in 2007. The seismic processing contract is to be awarded by first quarter 2009 and processing must be completed in a maximum of six months from receipt of input tapes
Nigerian independent South Atlantic Petroleum Ltd (Sapetro) may have commenced drilling the near-field exploration well Seme SW, around the Seme oil field, in Block 1. The Sèmè SW target had previously been identified but whether this becomes the company’s first operated well in Benin remains to be seen. It is understood the Noble Drilling’s jack up rig ‘Don Walker”, currently in Cameroon, has been contracted to do the job as the structure lies in around 30metres of water. Block 1, including Sèmè field, covers 551 sq km in the shallow waters of the Benin Embayment, at the maritime border with Nigeria.
It was awarded in December 2004 and is held 100% by Sapetro. In March 2007, Sapetro completed a 360 sq km 3D seismic survey over the Sèmè field and its environs. It is believed this data will form the basis for a redevelopment plan of the Sèmè field aimed at putting the field back into production. Sapetro has a share in the development of the Akpo deepwater field off Nigeria. Its chairman is General Theophilus Danjuma, formerly minister of defense under Olusegun Obasanjo.
FRENCH MAJOR TOTAL HAS SUCCESSFULLY appraised its 2005 discovery Mostarda-1. The appraisal well Mostarda 2G1, was suspended at a Total Depth of 5,150metres subsea, but TOTAL did not provide details of the hydrocarbon find. Mostarda 1 was drilled in the Ultra deepwater Block 32 in late 2005 and flowed 5,347 BOPD of 30 degree API oil.
NORWEIGIAN OPERATOR, STATOILHYDRO has mapped out plans for a large two dimensional 2D seismic coverage of the 11,099- sq km deepwater block 2, frontier acreage of the Indian Ocean in the course of 2008. A first well is still far in the distance, but state hydrocarbon company Tanzanian Petroleum Development Corporation TPDC has a 10% back-in right in the event of a commercial find..
A PARTNERSHIP CONSISTING OF AFRICA Oil and Range Resources have secured a drilling rig for their proposed 2008 drilling programme in Puntland. The first well is planned to spud in July. The rig contract became effective February 19 and covers the drilling of two wells with a two well option.
The ETP rig No 3, newbuild rig currently being constructed in the Shengli, and scheduled for completion in May, will mobilize to Jebel Ali in Dubai before moving onto Somalia. ETP rig No 3 Is owned by Singaporean firm Energi Tata Persada Pte Ltd. The rig is a 1,500 High Pressure(HP) unit, equipped with the latest drilling technology, including a top drive and three 1,600 HP pumps. The camp facility will house up to 150 persons. ETP will also provide the trucking and hoisting equipment as part of its contractual obligations.
NIGERIAN INDEPENDENT ORANTO IS continuing a 1,500-sq km Marine 3D seismic survey started offshore Sierra Leone on the West African coast. The essential block is SL-5 and is being executed for Oranto by the Chinese owned Bureau of Geophysics BGP vessel Pioneer SV. Oranto says that the shoot will likely extend over nearby SL-4, and the job may be coupled to a planned 1,500 – sq 3D shoot in Oranto’s LB-12 in neighbouring Liberia.
THE KILAWANI NORTH-1 (KN-l) WELL has encountered what operator Aminex describes as substantial natural gas column, in offshore Tanzania’s Nyuni/East Songo- Songo license area. The fluid is in Lower Cretaceous sandstones, the same formation that produces gas commercially in the neighbouring SongoSongo gas field. Preliminary evaluation indicates a gas-water contact approximately 30 metres deeper than at the adjacent Songo-Songo Gas field. This indicates that the KN-1 discovery is in a separate structure to the Songo-Songo field, thus enhancing the prospectivity of the remaining leads and prospects within the Nyuni licence. Formation pressures confirm the presence of gas over a gross interval of approximately sixty metres. KN- 1 was drilled as a vertical hole to a depth of 2030 metres (6,687 ft), ahead of schedule. Electric logging has been completed. KN- 1 will now be completed as a gas production well pending hook-up for production and a test will be conducted to determine flow capacity and reservoir properties. Further appraisal drilling will be required to define the extent of this discovery. This is a positive outcome for the potential of other exploration prospects and leads in the Nyuni licence area. KN- 1 also encountered minor oil shows in the Neocomian reservoir section, as well as confirming the presence of potential reservoirs in the Tertiary section at an earlier stage in the well.
The Nyuni/East Songo-Songo licence is a component of Aminex’s acreage portfolio in East Africa, which includes the highly prospective Ruvuma Basin area of Tanzania as well as large acreage positions in Madagascar and Kenya, on all of which new seismic has now been acquired. Aminex is also currently participating in the Malak- 1 exploration well in the West Esh ElMeilahah concession in Egypt, which spudded on 25 February and is drilling ahead on schedule. “We are now seeing the first real fruits of our work on the East African margin over several years, says Aminex chairman Brian Hall. “Our exploration team has long believed in the potential of this area, both for oil and gas. KN-1 is a totally new, deep structure which opens up several avenues for further exploration on the licence and strengthens the case for oil on the East African margin. This frontier area, where we were an early pioneer, is now the subject of strong industry interest. Credit is due to our explorationists and operations personnel, as well as to our JV partners who have made a strong technical input to this project and to TPDC (Tanzanian national oil company) and the Tanzanian Ministry who have provided invaluable cooperation from the outset. ”Partners in the license are Ndovu Resources Ltd. (Aminex subsidiary and operator) 40%, RAK Gas Commission with 25%, Key Petroleum Ltd. holds 20%, East African Exploration Ltd. 10%, and the remaining 5% is held by Bounty Oil & Gas Ltd.
A 90 DAY, 700 SQ KM 3D SEISMIC SHOOT ended in February 2008 in the 1,305-sq Bock J offshore Equatorial Guinea. The crew was BJP Pioneer SV.
THE DRILLSHIP DEEPWATER Pathfinder moved from the deepwater Agbami 3 ST2 to spud Aje 4 in the first week of February. Aje 4 is located in less than 200metres of water. By February 18, two casings had been run in the well and the operation was in the 12-1/4’ hole. The technical operator, Chevron (18%), doesn’t plan to test this well in the event of a successful outcome. The idea is to run production casing and suspend the well as a potential producer. Aje 4 is expected to confirm that the field indeed has 1 .2Trillion cubic feet of gas as well as up to 200million barrels of oil. The first two wells encountered two main hydrocarbon rich reservoirs, each of Turonian and the Cenomanian age, but Aje 3 encountered the Cenomanian reservoir at a level significantly down-dip from the discovery well, as well as below the existing oil-water contact defined in Aje-2. The well did indeed “see” the Turonian level updip of the two earlier wells and located above the gas water contact encountered in both Aje-1 and Aje-2 but the presence of gas in the reservoir could not be tested due to poor reservoir properties at the Aje-3 location. Participants in the 1,840 sq km OML 113, which contains the Aje field, include Yinka Folawiyo (holding operator 60%),Vitol Exploration (12.83%), Energy Equity Resources (6.50%) as well as Providence Resources (2.67%).
DEVON ENERGY, THE LARGE American Independent, is embarking on a three-well programme to evaluate the Venus oil discovery in Offshore Block P in Equatorial Guinea. The Crosco semi-submersible rig “Zagreb 1 “is being deployed to drill three locations, to test some of the identified prospects in the vicinity of the Venus discovery. Devon’s geoscientists have identified at least three play types along the western limit of the block, one at Tertiary level and two in the Cretaceous. From north to south of the block, Devon has defined such playtypes as Luna (channel complex overlying the Upper Cretaceous series), Estrella, Marte, Jupiter and Sol (Tertiary valley fill). The prospects, which are located in the southern portion of the block, have similarities to Upper Cretaceous structures in former Block G. Block P has an area of 1.619 sq km and covers grid blocks H- 17, 1-17, H- 18 and 1-18 in the Rio Muni Basin. The acreage lies mainly on the shelf, between the coastline to the east, and Block H (Atlas) plus Block L (Chevron) to the west. Devon made the Venus oil discovery in September 2005. The P-2 wildcat encountered about 45m of net oil pay in Upper Cretaceous (Campanian?) sands. The well was spudded in August 2005 with the semi-submersible Global Santa Fe rig Aleutian Key, but ended at a depth of about 2,160m. A sidetrack kicked off and reached a final depth of about 2,270m. Well P2ST encountered 35m of net oil pay downdip, but no tests were carried out. Devon says that the reservoir encountered in Venus-I is composed of multiple channel sands, similar in type to the sands in Zafiro. The operator is carrying out detailed seismic interpretation and AVO analysis. If the appraisals work, the accumulation could be brought on-stream by 2008. Well P-2 is located in the southwestern part of the acreage, about 2km south of wildcat P-1 and 30km NW of Bata in 253m of water depth. Early in October 2004, Devon had plugged and abandoned its first well in Block, wildcat P-1 on the Jupiter prospect. That well was also drilled with the semi-submersible GSF “Aleutian Key”. The company assumed that no oil show was encountered in that exploration programme. P-I is sited in 219m of water, some 60km north- northeast of the Ebano field and 30km northwest of Bata in the southwestern portion of the tract. The interests in the licence are shared between operator Devon with 38.4% and Petronas 31%, DNO 5% and Atlas Petroleum 5.6%. State hydrocarbon company GEPetrol is 20% carried.