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Indonesia Oil & Gas Fields - South Sumatra.

Several companies operate in South Sumatra, mainly an oil province, including Stanvac, Pan Pacific's Enim Oil, Husky Oil of Canada, and Golden Spike of Bermuda. Their fields are small. Stanvac has several fields found since the early 1970s, with hydrocarbons reservoired in clastic and carbonate rocks. Stanvac has oilfields in Central Sumatra, which are small as well. Asamera Oil Indonesia (AOI), a unit of Gulf Canada Resources, has oil and gas fields in Asamera region in South Sumatra. Some of these fields are old (like Kluang, found in 1913). In early 1991 it made a significant gas discovery at the Gelam-1 well, in its Corridor PSC Block which was extended for 20 years in 1989. Gelam-1, 35 km north of AOI's Bentayan oilfield, tested 24.8 MCF/day of gas and some condensates. In discoveries made subsequently, AOI found that Gelam was a large field extending north to another block held by Saga Petroleum of Norway (50%) and Pertamina (50%). A plan to develop the whole field jointly with AOI was approved in November 1994. This and other Corridor fields, including the Dayung giant, Suban and the 34% CO2-Sumpal field, went on stream in late 1997, and full production began in late 1998. With a 540 km Corridor Gas Pipeline to the north completed in late 1998, the fields supply 310 MCF/day to CPI's EOR system at Duri, and 40 MCF/day to other users in North Sumatra. A 283km extension of the Corridor pipeline is to be built to supply a power plant on Batam Island near Singapore. This is part of Pertamina's programme for a more efficient exploitation of several small gas fields in Sumatra. In the Corridor PSC, AOI holds 54% and is the operator, with a unit of Talisman Energy of Canada holding 36% and Pertamina 10%. A revised 20-year PSA for Corridor was signed with Pertamina in 1996. AOI pledged to invest $65m over nine years on another phase of exploration and booked 670 BCF of net gas, after deducting its CO2 content which will be stripped away on extraction, and 3.6m barrels of net liquids in reserves. Future gas developments was to carry a revised 65/35 production split in favour of Jakarta, instead of the standard 70/30 split. To cover part of the $650m cost of developing its share of the field and the other Corridor fields, the AOI-led group in February 1997 signed an agreement with a consortium of 19 lenders for credits of up to $450m, arranged by Itochu Corp and Sumitomo Bank of Japan, Chase Manhattan of the US and DKB Merchant Bank of Singapore. Development included the drilling of 40 wells in 1997. Another Gulf Canada unit, Asamera South Jambi, operates the nearby South Jambi B PSA block. There it found in late February 1996 an important gas field at Bungkal, 13 km north-west of Dayung and near the gas pipeline to North Sumatra. The dry gas has 60% CO2 content. Production of net gas began in early 1998 and now is supplied to the gas pipeline to North Sumatra which passes through Jambi province. In this block, Asamera holds 45%, with 30% held by Total and 25% by Pertamina. Asamera has made several gas discoveries on the block since then. Pertamina operates a gas field in a nearby block, Jambi Merang, where reserves are estimated at more than 350 BCF. The gas is being supplied to North Sumatra by the 540 km Corridor Gas Pipeline. In North Sumatra, Asamera has Block A which it operates with a 50% interest in partnership with Aceh Gas & Oil Co. of Japan (50%). There, it has discovered a major CO2/gas field similar to that of Natuna. Its first well, Langsa-1, in 1992 tested 36 MCF/day of gas consisting of 81% CO2 and only 19% hydrocarbons. In the subsequent years, it found three fields, Alur Siwah, Alur Rambong and Julu Rayeu, with a total of 585 BCF of net gas reserves. These are being developed to produce about 200 MCF/day of raw gas and supply 120 MCF/day of processed gas to Mobil's Arun field, which is 45 km away, by 1999. From there the gas will be pumped through Mobil's existing system to reach the Arun LNG complex, 80 km north-west of Block A. This will yield about 45 trillion BTU of LNG for export to East Asia and 4,100 b/d of condensate. Pertamina executives say after Exxon's expected success in separating gas from CO2 commercially at Natuna, several fields of this category, including Asamera's, would be developed. Gulf Canada Resources, which sold 27.6% of its Indonesian holdings in Sept 1997, is seeking to sell all its interests in the country by mid-1999. It is holping to get about $570m, to help reduce its debts. These include a stake in the West Natuna gas project and a stake in Timor Sea's Jabiru and Challis oilfields. Santa Fe Energy Resources, operating in different blocks in Indonesia, is producing over 21,000 b/d of 37 deg. API, 0.4% sulphur oil from its Mudi field and nearby structures in South Sumatra. The field went on stream in early, 1998 with a reserve of 50m barrels. In late 1998, Santa Fe made a 5th gas discovery through the Gemah well, which flowed at 600,000 CM/day about 5 km south of two previous finds. Santa Fe has an agreement to pipe the gas to Singapore, using a spur from the Corridor Gas Pipeline. In its South Sumatra Jabung Block, Santa Fe made a significant discovery in late 1995 through its Geragari Utara-1 well, which tested 5,100 b/d of 50 deg. API oil, 30 MCF/day of gas and 350 b/d of condensate from various sand intervals in the Miocene Gumai formation. In late 1996 it made a bigger discovery 7 km south-south-east of that wildcat, through Makmur-1, which six intervals at a total depth of 1,833 metres. The first three zones tested an aggregate 3,915 b/d of light oil and 6.8 MCF/day of gas. One of the intervals between 1,115-1,135 metres tested 2,915 b/d of 50 deg. API oil on a 48/64-inch choke with a flowing tubing pressure of 485 psi. In August 1995, its North- East Betara-1 wildcat tested three intervals totalling 84 net feet of pay and yielded a combined 22 MCF/day of gas and 420 b/d of condensate. But the gas' CO2 content was 55%. In 1991-95, Santa Fe drilled 16 exploration wells and made six discoveries on its blocks. These include a tract on Vogelkop peninsula in Irian Jaya, for which it got a 20-year contract extension from Pertamina in the autumn of 1996 and the company pledged to spend $10.2m on exploration over five years. In late 1996, the company got a PSC for the 8,595 sq km Pagatan Block in the Asem-Asem Basin off South-East Kalimantan. The Widuri Block of Maxus, in South-East Sumatra's offshore, has two major oilfields producing since late 1990 together with smaller structures. Intan and Widuri were found by Maxus in the 1980s. With Widuri brought on stream in late 1990, their combined capacity is over 250,000 b/d. Widuri alone produces about 90,000 b/d. Widuri oil is waxy but with low sulphur suitable for direct burning by power plants in Japan and other markets. Maxus' other field, Cinta, produces about 50,000 b/d. A processing complex takes the output from more than 60 wells on seven remote- production platforms. Then the crude stream is pumped for storage in a permanently moored tanker, Maxus Widuri. The fields are to be developed further by Maxus. This block's recoverable oil reserves have been estimated at 235m barrels. In 1991-95, Maxus drilled 39 exploration wells in Indonesia and had nine discoveries.
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Publication:APS Review Gas Market Trends
Geographic Code:9INDO
Date:Mar 8, 1999
Previous Article:Indonesia Oil & Gas Fields - North Sumatra - Mobil & Arun LNG.
Next Article:Indonesia Oil & Gas Fields - East Kalimantan.

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