Development Planning and Reservoir Management in the Duri Steam Flood

Gael, B.T. (PT Caltex Pacific Indonesia) | Gross, S.J. (PT Caltex Pacific Indonesia) | McNaboe, G.J. (PT Caltex Pacific Indonesia)

OnePetro 

Abstract The overall objective of reservoir management and development planning for the Duri field is to maximize project value. Key elements of Duri's reservoir management practices include: injecting steam in new patterns at rates up to about 1.2 BCWEPD/NAF or the maximum rates achievable below fracture pressure; distributing the steam into reservoir layers in proportion to their h So; maintaining these rates until steam breakthrough occurs in multiple wells in a pattern; then performing injector wellwork to shift steam out of the breakthrough layers while continuing initial rates into the non-breakthrough layers. The area-wide rate reduction schedule caused by these shifts resembles a heat balance (Vogel) rate reduction schedule. The steam that is shifted out of an old steamflood development area becomes the supply of steam for the start up of a new area. Key elements of Duri's development planning practices include: obtaining sufficient reservoir information to be able to predict performance of all areas in the field; dividing the undeveloped parts of the field into steamflood areas that are logical and will fit the steam availability and construction scheduling constraints of the project; ranking the new projects by their profitability; and installing them at a schedule that matches the steam shifts out of the old areas with the ramp up of the new area so that steam plant capacity is fully utilized. This paper discusses the interrelationships between reservoir management practices, development planning, and the maximization of overall DSF project value. Introduction The maximization of the value of the Duri steamflood presents several challenges. Roughly half of the Duri field is currently being steamflooded, with the remainder of the field to be divided into several additional steamflood project areas. These additional areas will be put on injection at approximately two-year intervals. Since the total steam generation capacity at Duri is fixed, starting up a new area requires that steam injection rates be reduced in existing steamflood areas. Conversely, Duri's reservoir management practices will result in rate reductions in existing areas, requiring that a new area be ready to shift the steam to if steam plant capacity is to be fully utilized. The timing of these steam shifts must be chosen to maximize the potential of both the old and new areas. Therefore, the development planning efforts for future steamflood areas are closely linked to the reservoir management practices in existing steamflood areas. FIELD LOCATION AND DEVELOPMENT HISTORY The Duri field, operated by PT Caltex Pacific Indonesia (CPI) under a production sharing contract with Pertamina, is located in Riau province of central Sumatra about 120 km northwest of the city of Pekanbaru (Figure 1). It is the second largest oil field in Indonesia in terms of OOIP. The Duri steamflood (DSF) is the largest steamflood in the world, currently injecting about 1.25 MMBCWEPD of steam and producing about 300,000 BOPD (Figure 2) through more than 3000 wells. P. 533

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