A multiphase flow meter named PhaseTester has been developed for determining oil, water, and gas production rates simultaneously. This new approach of well testing delivers significantly improved data quality and availability, allowing quick well performance trend analysis and immediate well diagnosis. Rapid, accurate production diagnosis allows timely decisions without prior well information or standard rate stabilization periods resulting in shorter, more reliable well tests stored in an easily accessible, user-friendly database. The PhaseTester provides a comparatively lighter operation unit and reduces risk of human error resulting in improved safety. Compared to conventional units, the physical size of the PhaseTester is usually half the size and the extensive pressure lines and safety devices are reduced. The meter is environment friendly since all the well effluents are returned to the production flowline without the need for separation or burning of hydrocarbons during the test. Obtaining periodic, accurate well test measurements is the key factor in Vico Indonesia Indonesia's well production optimization. The PhaseTester was introduced to monitor and optimize the production performance for gas lift wells. Changes in well performance were observed immediately allowing the operations engineer to quickly analyze the production characteristics and make decisions based on true accurate real time test data. Selected case histories demonstrate the results of these tests. Introduction Vico Indonesia operates the Sanga-Sanga Block in Indonesia as a Production Sharing Contractor to PERTAMINA, the Indonesian National Oil Company. The Sanga-Sanga Block is located in the Mahakam delta of East Kalimantan, Indonesia (Figure 1) near the city of Balikpapan and consists of four major fields producing approximately 1.3 BSCF/d of gas and 50,000 STB/d. Periodical well testing is the key factor in monitoring well performance. Two conventional trailer test units have been used for the past three years resulting in testing on average only two wells daily. The PhaseTester provides the freedom to acquire more daily well tests. The unprecedented ability of this multiphase flowmeter to accurately perform instantaneous flow rate measurements in challenging slugging flow conditions allows operations engineers to evaluate in real time the effect of small production setting changes (choke sizes, gas lift volumes and pressures, etc.). A gas lift performance curve can be generated rapidly and the operator can leave the well on the maximum production setting immediately after the test. Multiphase well testing provides well data in a digital format that can be interpreted and stored quicker than a standard test separator. The fast acquisition systems monitor a well's 'heart-beat' throughout the test displayed in real time. This provides the capability to detect production trends as they occur allowing the user to terminate testing as soon as adequate information is obtained rather than analyzing data after a pre-determined test period. Fluid property or flow regime changes do not affect the flow rate measurement.
Proposal VICO Indonesia is an Oil and Gas Company operating the Sanga-Sanga PSC inEast Kalimantan. This PSC comprises of four operating assets: Nilam, Mutiara, Semberah and Badak. The depositional environment consists of fluvial-deltaicsands with oil and gas bearing sandstone formations stacked on top of eachother, there are on average ten to twenty zones per well. Exploiting thesereservoirs to their maximum potential to meet the gas delivery to Bontang LNGplant is the object of the asset teams. Maximizing asset value by increasingproduction with lower investment is very important within the VICOorganization. In order to achieve the above objective at optimal costs, a lot of emphasisis being given to rigless activities. The main activity is to open thesestacked gas bearing sandstone formations by adding perforations either bywireline or by utilizing extreme under balanced perforating techniques. This paper focuses on the utilization of state-of-the-art software, perforation performance module (PPM) in conjunction with extreme under balanced(EUB) perforating technique for maximizing gas production from the deep lowpermeability and low porosity gas bearing reservoirs. This paper presentsvarious cases showing how effectively and economically these deep sandstoneformations can be completed to maximize the return on investment (ROI). The PPMwas utilized to predict the performance from these reservoirs. The actualpost-job results were then used to verify the predictions. This was essentiallyto assist VICO in making the decisions in line with the economic benefits forvarious perforating techniques. Reservoir Description VICO Indonesia's Oil and gas fields are located in the Kutai Basin, EastKalimantan, shown in Figure 1. The sedimentary system starts fromMiocene age until recent. At the end of the Miocene period the ancient deltawas formed. The delta was formed and moved from west to east, uplift createdfolds. Two of the most common sandstone facies recognized in the Miocenesediments are fluvially dominated, distributary channel and tidally dominated, delta front bar deposits. Commercial hydrocarbons can be produced from highlyquartzitic channel sandstone to a maximum depth of burial of 15,000 ft. Ingeneral, distributary channel facies have a relatively higher porosity comparedto a front bar. The sedimentary system is divided into three sequences. The upper and middlesequences identified have good reservoir quality (porosity and permeability)while the lower sequence has poorer reservoir quality. The lower sequence (deepgas sand) exists in all VICO fields and offers a significant volume of gas tobe exploited. From the petrophysical calculation, permeability is less than 5md and porosity is less than 12% while the pressure is slightlyoverpressured.
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.
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