IN WESTERN AUSTRALIA - Department of Mines and Petroleum

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12 In 2002, a major remote sensing programme including a geotechnical piston core survey was undertaken in the five blocks to help understand the likelihood of a working petroleum system. Early in 2003, BHP Billiton drilled the Maginnis 1 well in WA-302-P. Maginnis 1 was located in approximately 1300 m of water and was drilled by the Jack Ryan dynamically positioned drill ship. BHP Billiton, on behalf of the respective Joint Venture partners, also acquired a combined 510 km 2 of 3D seismic data over permits WA-303-P and WA-304-P. The focus has been to incorporate the Maginnis 1 results and data and interpret the seismic data. BHP Billiton is the operator in all five blocks. The ownership interests are: • WA-301-P, Kerr McGee, 50%; BHP Billiton, 50% • WA-302-P, Texaco, 33%; Kerr McGee, 33%; BHP Billiton, 33% • WA-303-P, Texaco, 33%; Kerr McGee, 33%; BHP Billiton, 33% • WA-304-P, Kerr McGee, 50%; BHP Billiton, 50% • WA-305-P, Texaco, 33%; Kerr McGee, 33%; BHP Billiton, 33%. Carnarvon Basin PWA April Edition - 2003 Review BHP Billiton Petroleum is the operator of exploration permits WA-255-P, WA-155-P(1) as well as retention lease WA-12-R (Macedon-Pyrenees fields) and production licences WA-10-L and WA-12-L (Griffin-Chinook-Scindian complex), all located within the offshore Carnarvon Basin, Western Australia. During the second half of 2003, our Western Australian exploration focus was on the Exmouth Sub-basin of the Carnarvon Basin, with drilling activity in permits WA-155-P(1) and WA-12-R, and exploration studies following an active drilling programme in WA-255-P. In WA-255-P (BHP Billiton 50%, operator), data gathered from a 4-well programme undertaken from February to June 2003 were analysed and results interpreted in preparation for a renewed drilling campaign proposed for the first half of 2004. Our exploration activity in WA-155-P(1) (BHP Billiton 39.999%, operator) focused on extension of the Pyrenees-Vincent heavy oil play. An exploration well, Ravensworth 1, was drilled in July 2003 using the Sedco 703, approximately 10 km southeast of the Vincent oil and gas field. The well encountered a 37 m oil column with a 7 m gas cap in high quality sandstones and after sidetracking to acquire core across the reservoir, Ravensworth 1 was plugged and abandoned, as planned. The Ravensworth discovery was followed up in ChevronTexaco’s Greater Gorgon Area (Image courtesy of ChevronTexeco) October 2003 by an exploration well on the adjacent Crosby feature in WA-12-R. Ravensworth and Crosby are currently being evaluated, along with several undrilled prospects in WA-12-R inbetween Crosby 1 and West Muiron 5. The Van Gogh 1ST well was drilled in WA-155-P(1) to test the northern part of the Vincent field, discovered by Vincent 1 (Woodside, 1999). The results of BHP Billiton Petroleum’s Van Gogh 1ST and Woodside’s Vincent 1 and 2 wells are currently being evaluated. ChevronTexaco Barrow Island / Thevenard Island Licences ChevronTexaco continued to develop its exploration portfolio within the exploration and production licences of the Barrow and Thevenard areas. Exploration focus was on oil plays close to existing production facilities. No exploration drilling was undertaken in the Barrow and Thevenard Island regions during 2003. The renewal of Barrow Island onshore exploration permits EP61 and EP62 was granted in 2003. Exploration permit TP/2 is currently subsisting awaiting formal renewal approval. In the Thevenard area, the only activity was the assignment of ChevronTexaco Australia’s interest in exploration permit TP/3 to Santos. There are no planned exploration activities for 2004 in the Barrow Island or Thevenard Island regions. Greater Gorgon Area Gas Assets There were no exploration drilling activities in 2003 within the Greater Gorgon Area exploration permits in the area including and to the west of the Gorgon field. Activities during the last twelve months in the Greater Gorgon Area were focused on retaining the recently discovered gas in WA-267-P and WA-25-P and extensions of these resources into WA-253-P. Ten retention leases have been awarded to ChevronTexaco Australia and their partners during the last two years covering the Iago, Geryon, Orthrus-Maenad, Urania, Io-South, and Io-Eurytion gasfields (from WA-25-P, WA-267-P, and WA-253- P). The remaining WA-267-P and WA-25-P graticular blocks were surrendered during 2003. In addition, and concurrent to this, marketing efforts for the sale of the Gorgon Area gas (which includes Spar, West Tryal Rocks and the Gorgon gasfields) was the main focus for ChevronTexaco Australia Pty Ltd during 2003. These three Gorgon Area gasfields were renewed for a further five years in August 2003. Seismic acquisition was undertaken in WA-253-P (Wheatstone 2D MSS), WA-268-P (Champagne 2D MSS) and WA-205-P (Acme 3D MSS) to fulfil their respective work commitments. Wheatstone 2D MSS comprised 625 line km while Champagne 2D MSS 2430 line km and Acme 3D MSS 220 km 2 . The
acquisition had incident free operations. Texaco Australia Pty Ltd participated in the drilling of the Mobil operated Jansz 3 well. The well was successfully production tested, with a peak rate of 2 Mm 3 /d (72.6 MMcf/d). A major event during 2003 was the announcement of the ratification of the State legislation that will allow Gorgon limited access to Barrow Island for the construction of a gas processing plant. Many other approvals are required before Gorgon can start construction of the plant notwithstanding the stringent environmental approvals. Two large seismic programs have been planned for 2004 in the Greater Gorgon Area. The Chandon 3D MSS will focus on the Chandon Prospect in WA- 268-P and the Io-Jansz 3D MSS will further delineate the large gas resource discovered by the Io and Jansz wells over the last several years. Acquisition is scheduled to start in February 2004. The major focus in 2004 for the Gorgon Area Gas Team will be the continued commercialisation effort for the Gorgon gas. To this, numerous positions have been advertised in the national newspapers looking for engineers and other project experienced personnel. Eni Australia In 2003, Eni Australia was actively involved in 11 exploration permits in offshore Australian waters and eight of these were in Western Australian waters. As operator, Eni acquired 5300 km of 2D seismic in the Houtman Sub-basin and reprocessed a further 5000 km of 2D seismic. As non-operator, Eni participated in two exploration wells, Wigmore 1 and Weasel 1. Activity planned for 2004 as operator includes the acquisition of 600 km 2 of 3D seismic and the drilling of one exploration well on the Woollybutt production licence. The company also intends to participate in at least two other exploration wells during the year. Kimberley Oil Due to the forthcoming granting of Application Area 2/96-7, which contains the oil and gas-bearing Pictor anticline, the company commissioned an engineering appraisal of the economic viability of horizontal drilling into the oil and gas-bearing zone. The study concluded that horizontal drilling into the Pictor Anticline is likely to achieve economic oil production rates and that estimated recoverable oil reserves total 6.4 GL (40 MMbbl). Kimberley Oil will be seeking a farm-in into the exploration permit, subsequent to the granting of Application Area 2/96-7, so that a horizontal well is drilled into the Pictor Anticline. A commitment exploration well is due in EP129, and the company is seeking a farm-in partner for the drilling of Boundary Southeast 1. A commitment exploration well is due in EP391, and the company is seeking a farm-in partner for the drilling of a test well on the crest of the Yulleroo Anticline. Nexen Energy On the exploration front, Nexen had been seeking partners to participate in the exploration of WA-239- P, in the Browse Basin, offshore Western Australia. The block is situated on the Yampi Shelf on the eastern margin of the basin, approximately 730 km southwest of Darwin. It has an area of approximately 4700 km 2 and only two wells have been drilled in the permit. However, the farm-out efforts were unsuccessful and Nexen surrendered the permit. Roc Oil Permit Interests As at 31 December 2003, Roc Oil (WA) Pty Ltd (ROC) is the operator of four permits in the Perth Basin and participates in another permit, as detailed in Table 2. Effective 1 April 2003, ROC acquired Arc Nexen’s Buffalo oilfield (Image courtesy of Nexen Energy) Table 2: ROC’s W.A. Permit Interests as at 31 December 2003 PWA April Edition - 2003 Review 13 Energy’s 7.5% interest in WA-286-P (which includes the Cliff Head oilfield). ROC farmed into EP413 effective 1 April 2003, by acquiring Victoria Petroleum’s 0.25% equity in the permit, which contains the Jingemia oilfield. In mid-2003, ROC acquired an option to acquire Norwest Energy’s 7.5% equity in WA-226-P. This option may be exercised pending the review of Macallan 3D seismic data. In addition, ROC announced on 18 December 2003 that it will exercise an option with Voyager Energy Limited to acquire a 50% interest in, and operatorship of, the gazettal block WO3-14, which is contiguous with three licences in which ROC already hold interests, and is on the same geological trend as the Cliff Head oilfield. Drilling Activity In 2003, ROC participated in three exploration and four appraisal wells in the Perth Basin. The exploration wells did not encounter significant hydrocarbons, while all appraisal wells were successful. Permit Basin ROC Interest Operator WA-286-P Perth (Offshore) 37.5% Roc Oil (WA) Pty Ltd TP/15 Perth (Offshore) 20.0% Roc Oil (WA) Pty Ltd WA-325-P Perth (Offshore) 37.5% Roc Oil (WA) Pty Ltd WA-327-P Perth (Offshore) 37.5% Roc Oil (WA) Pty Ltd EP413 Perth (Onshore) 0.25% Origin Energy Developments Pty Ltd WA-226-P (Option to acquire) Perth (Offshore) 7.5% Origin Energy Developments Pty Ltd
Page 1: APRIL 2004 PETROLEUM IN WESTERN AUS
Page 4 and 5: 2 PWA April Edition - International
Page 6 and 7: 4 PWA April Edition - Minister’s
Page 8 and 9: 6 PWA April Edition - Director’s
Page 10 and 11: 8 PWA April Edition - 2003 Review s
Page 12 and 13: 10 PWA April Edition - 2003 Review
Page 16 and 17: 14 Two wildcat wells in WA-286-P (M
Page 18 and 19: 16 bearing. No significant hydrocar
Page 20 and 21: 18 The oil is a good quality 49.2°
Page 22 and 23: 20 PWA April Edition - 2003 Review
Page 24 and 25: 22 PWA April Edition - Resources Br
Page 26 and 27: 24 PWA April Edition - Magnetotellu
Page 28 and 29: 26 PWA April Edition - Magnetotellu
Page 30 and 31: 28 PWA April Edition - State Acreag
Page 32: 30 PWA April Edition - State Acreag
Page 35 and 36: the contractors they select have th
Page 37 and 38: y introducing appropriate organisms
Page 39 and 40: International Risk Consultancy It w
Page 41 and 42: Table 1. Reserves as at 31 December
Page 43 and 44: Gingin 0 48,545 3,169 Gipsy 315,750
Page 45 and 46: KEY: Classification 2D: 2D Reflecti
Page 47 and 48: PWA April Edition - Petroleum Wells
Page 49 and 50: Wandoo Petroleum Pty Ltd * Apache N
Page 51 and 52: PETROLEUM (SUBMERGED LANDS) ACT, 19
Page 53 and 54: WA-15-R Active H 11 19 Apr 2006 Tex
Page 55 and 56: * ChevronTexaco Australia Pty Ltd T
Page 57 and 58: Norwest Energy NL Roc Oil (WA) Pty
Page 59: EXECUTIVE Director General Jim Lime

IN WESTERN AUSTRALIA - Department of Mines and Petroleum

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