This paper was aektad r% preaekaticm by an SPE Progrsm Committee foilo$ing review of information ccirtainsd in an atsfract submittad by the suthor(s). Contents of the paper, ss presented, have not been reviswsd by the Society of Petroleum Engineers and are subjsct to comction by the suthor(s). The material, as presented, does not nacsssarily reflect sny postion of the Society of Petroleum Engineers, its officers, or members. Pspers presented st SPE rnaebkga are subjact te publication review by Edtirial Cemmitfees of the Ssciaty of Petroleum Enginaers. Ekctmnic reproduction, distrkation, or storage of any psrt of this paper for commercial purpmes without the witten consent of the Society of Petroleum Engineers is pmhibted. Pemksion to reprcduce in print is restricted to an aktract d not more than S00 v.wxls; illustiatimrs may n~ba copied.The abstract must contain conspicuous sckmmkdgrwnt of Mere and by Warn the paper was preaantsd. Write Librarian, SPE, P.O. @ox S33S30, Rxhardscm, TX75083-3S38, U.S.A., fax 01-972-952S435. AbstractDevelopment of a margkal oit field offers a unique set of challenges. These challenges were experienced in the development of VICO'S Semberah Fiel@ located in East Kalimantau of Indonesia. Semberah Field was originally thought to be a small oil accumulation in a mainly gas arw, therefo~, the facilities and development plans were conceived around a target of 5,000 BOPD. However, an aggressive development effort which included, in addition to moderate drilliig aud re-completions, an on going cost effective production optimization effort of both surface facilities and downhole completions have resulted in maintaining the oil production at a level of more than 12,000 BOPD for the last five years. This paper presents example of the ongoing development process of the Semberah field. Under a complex geological environment and multi-layered saudstone reservoir, the thin non-continuous oil sands encountered were initially developed without detailed planning. Rather than being driven by reservoir studies to guide the delineation pro-the life of the field is extended by cost effective production optimizNion that in tum encoumges further reservoir review.The optimization effo* have resulted in several significant upward reserve revisions of the Sembemh field. The whole field is now re-mapped with a probabilistic method in an attempt to capture the uncertainty of the sand development. Future efforts for additional improvement will be centered on a newly instituted multi-discipline asset team.
This paper was aektad r% preaekaticm by an SPE Progrsm Committee foilo$ing review of information ccirtainsd in an atsfract submittad by the suthor(s). Contents of the paper, ss presented, have not been reviswsd by the Society of Petroleum Engineers and are subjsct to comction by the suthor(s). The material, as presented, does not nacsssarily reflect sny postion of the Society of Petroleum Engineers, its officers, or members. Pspers presented st SPE rnaebkga are subjact te publication review by Edtirial Cemmitfees of the Ssciaty of Petroleum Enginaers. Ekctmnic reproduction, distrkation, or storage of any psrt of this paper for commercial purpmes without the witten consent of the Society of Petroleum Engineers is pmhibted. Pemksion to reprcduce in print is restricted to an aktract d not more than S00 v.wxls; illustiatimrs may n~ba copied.The abstract must contain conspicuous sckmmkdgrwnt of Mere and by Warn the paper was preaantsd. Write Librarian, SPE, P.O. @ox S33S30, Rxhardscm, TX75083-3S38, U.S.A., fax 01-972-952S435. AbstractDevelopment of a margkal oit field offers a unique set of challenges. These challenges were experienced in the development of VICO'S Semberah Fiel@ located in East Kalimantau of Indonesia. Semberah Field was originally thought to be a small oil accumulation in a mainly gas arw, therefo~, the facilities and development plans were conceived around a target of 5,000 BOPD. However, an aggressive development effort which included, in addition to moderate drilliig aud re-completions, an on going cost effective production optimization effort of both surface facilities and downhole completions have resulted in maintaining the oil production at a level of more than 12,000 BOPD for the last five years. This paper presents example of the ongoing development process of the Semberah field. Under a complex geological environment and multi-layered saudstone reservoir, the thin non-continuous oil sands encountered were initially developed without detailed planning. Rather than being driven by reservoir studies to guide the delineation pro-the life of the field is extended by cost effective production optimizNion that in tum encoumges further reservoir review.The optimization effo* have resulted in several significant upward reserve revisions of the Sembemh field. The whole field is now re-mapped with a probabilistic method in an attempt to capture the uncertainty of the sand development. Future efforts for additional improvement will be centered on a newly instituted multi-discipline asset team.
A number of tools are available for production improvements for wells where the cost of workover rigs cannot be justified or where workover rigs are unavailable. Recent literature has described some through tubing and rigless type workover innovations. This paper presents case histories explaining the use of production logging, coiled tubing, small bridge plugs, cement packers, acidizing and oriented perforating methods that resulted in excellent gas and oil production increases. Significant savings were experienced when compared to more conventional rig supported workovers. Cement packers placed by coiled tubing and oriented through tubing perforating have been used in several cases to restore inactive wells to commercial production rates. This paper describes two such attempts. In another case, extraneous water production was identified with a production log and shut off with a simple bridge plug setting. This was followed by acid stimulation of the gravel pack to restore the damaged interval to good gas rates. A third case is also presented to show several problems that were encountered in an older well. In order to select the appropriate technique and achieve the best results, a clear understanding of the problems, the objectives, and the available tools is needed for each case. This was accomplished by use of a multi-disciplinary team of various operating company and service company professionals involved in, the design and field operations to thoroughly review each proposal. Introduction VICO Indonesia operates several oil and gas fields in an area of East Kalimantan approximately 140 kilometers north of the city of Balikpapan (Fig. 1). These fields are operated under a production sharing contract with Pertamina, the Indonesian national oil company. VICO is the operator of a joint venture that began in the late 1960's and discovered commercial oil and gas in early 1972. Today the production rates are approximately 1.7 billion cubic feet (Bcf) gas, 40,000 bbl of condensate and 30,000 bbl of oil per day from VICO's four major fields. Gas is transported and sold through the liquification (LNG) plant at Bontang, and the liquids are blended and sold via the tanker terminal at Santan. Badak, the largest and oldest field, has now been completely developed by drilling. Because of the large number of reservoirs penetrated by wells in this field, workover operations will continue for many years to recomplete into shallower zones and repair existing completions. Now, in efforts to maximize the use of all wellbores and considering cost containment issues, production engineers at VICO have designed and performed several unique work programs that utilize rigless methods at a cost of about one-third the cost of similar rig supported workovers. These programs involve the use of production logs, coiled tubing, special cementing techniques, oriented perforating, inflatable packers, acidizing cement packers, computer modelling, small diameter tools, etc. Generally, very good success has resulted from the overall program. Gas production was increased by 130 million cubic feet per day (MMcf/D) and oil rates improved significantly in 1995. A few unexpected problems were encountered and these are also discussed. TDT Log, Coiled Tubing cement Packer, Oriented Perforating - Badak Well number 121 The original completion for Badak well number 121 was a dual gas well. By 1993 both zones had watered out, but interest in a zone behind casing led to a thermal decay time (TDT) log survey (Fig. 2). This survey showed that the three zones in the B-12 reservoir were not uniformly depleted since the middle interval was wet while the upper and lower sections contained gas. P. 35
Badak Field, located in East Kalimantan, Indonesiĩ s a giant onshore gas field with 181 wells and total gas deliverability of 1.3 billion standard cubic f=t (BSCF) per day. In many cases, gas from more than one well is commingled in the same flowline. This study concludes that commingling flowlines has been extremely cost effective over the life of the field. However, good initial design is required to anticipate future reservoir depletion and recompletion in order to achieve the best economic efficiency.
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