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The AAPG/Datapages Combined Publications Database

Indonesian Petroleum Association


29th Annual Convention Proceedings (Volume 2), 2003
Pages 1-21

Integrated Reservoir Modeling for Evaluating Development Opportunities in a Mature Oil Reservoir, Beras E-314 Reservoir, Onshore Kalimantan

Jim Forrest, Ade Sukmana, Firwan Aprizal, Mike Jackson, Simon Christian


The primary objectives were to accelerate recovery and increase reserves by a variety of future development opportunities including workovers, possible infill producers, water injection and/or gas injection projects. A reservoir re-development study was conducted that included (1) a deterministic reservoir geological model, (2) volumetric estimates of the original hydrocarbons-in-place, (3) estimation of gas lost during an early gas blowout, (4) a historymatched simulation model and (5) predicted results that can be used to perform economic analyses of the possible future development opportunities.

Within a few months, a 3-dimensional, 3-phase reservoir simulation model was developed based upon engineering, petrophysical, geophysical, and geological data and interpretations. The general geological model was one of multiple sand channels in a fluvial-deltaic environment. The model included 9 existing wells of which 3 wells were candidates for workovers. In addition, two inactive wells, Beras-04 and Beras-06, were evaluated for water injection and gas recycling projects. For new wells, the west flank area was prioritized for possible locations for new infill producers, and other potential new wells (infill producers and/or water injection wells) were located based upon simulation results.

Simulation results show that an Initial Oil-In-Place (IOIP) of about 50 MMBbls was required to obtain a good history match.

The Mutiara-44 well, which suffered a gas blowout in December 1993, lost an estimated 1.7 BCF during the blowout period. This volume was required to obtain a good match to the corresponding drop in pressure in late 1993 due to this event.

Ultimate field oil recovery for the existing wells (do nothing case) was predicted to be 51% recovery factor (RF) of IOIP (as of December 2018), compared to 40% recovery as of April 1, 2002. From predicted incremental field oil recovery, the best future development options were as follows:

• Beras-01 workover in September 2002

• water injection by conversion of Beras-04 in April 2003

• one new vertical infill producer on the west flank in July 2003

• plus gas injection through Beras-06 in January 2004

Economic and decision risk analyses are ongoing to evaluate the benefit of these projects. Additional data acquisition and analyses are also being considered to improve the reservoir characterization and the reliability of the predictions.

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