The Transformation of Poleng Field

Welker-Haddock, Mary; Park, Robert; Asjhari, Imron; Bradfield, John; Nguyen, Binh P.

doi:10.29118/ipa.412.681

Cited by 1 publication

(5 citation statements)

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“…A full description of the regional geology can be found in an IPA paper titled "The Transformation of Poleng Field". 1 The paper describes the regional and field geology in detail. Additional information on this area can be found in references 2 and 3, but a few of the key points from Reference 1 are included here for completeness.…”

Section: Structural and Stratigraphic Settingmentioning

confidence: 99%

“…1 One of the main points to note from the reservoir geology is that the reef structures tend to be steep walled and encased in the marine shales and silty carbonates of the overlying Rancak formation. This setting indicates that aquifer support should be limited because aquifers, although thick, are areally confined.…”

Section: Structural and Stratigraphic Settingmentioning

confidence: 99%

“…The production was suspended in 1978, when the field became sub-economic, suffering from high gas-oil ratio production and lack of gas sales in the area at that time. 1 In 1998, the Korea Development Company Ltd. (Kodeco) re-activated the field by drilling several horizontal wells. At the time of this study, a total of 12 wells (2 wells were sidetracked) were available in the field including 11 active producers.…”

Section: Introductionmentioning

confidence: 99%

“…The new seismic interpretation along with additional well data proved up a larger productive area. 1 A black-oil simulation study conducted in 2001 estimated the Original Oil and Gas In-Place (OOIP and OGIP) of 74 MMSTB and 139 BSCF, respectively. The resulting simulation model had too many layers for practical use and contained some coarse modifications that were applied during the history-matching process.…”

Section: Introductionmentioning

confidence: 99%

“…The primary objective of the study was to accelerate recovery and increase reserves. Several possible future development opportunities were evaluated including gas and water injection, installation of booster compression, workover, and (1) a deterministic reservoir geologic model, (2) volumetric estimates of the original hydrocarbons in-place, (3) a historymatched simulation model and (4) predicted results that can be used to perform economic analyses of the possible future development opportunities.…”

Section: Introductionmentioning

confidence: 99%

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Reservoir Simulation Challenges for Modeling a Thin Volatile Oil Rim With Large Gas Cap in the Poleng Field, Kujung-I Oil Reservoir, East Java Basin, Indonesia

Forrest

Sukmana

Suhana³

et al. 2005

SPE Asia Pacific Oil and Gas Conference and Exhibition

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThis paper explores the difficulties in modeling an oil rim with a large gas-cap using black-oil and compositional formulations. The example is from the Poleng field located in the Poleng Block, East Java Basin, Indonesia. This reservoir is a reefal carbonate system with a limited aquifer within the Kujung-I interval.Production from the field commenced in 1975, was suspended in 1978 and re-activated by Kodeco in 1998. In 2002-03, a full-field study was conducted to re-evaluate the OOIP and OGIP and investigate future development options such as booster compression, gas and/or water injection, workovers, and infill wells. For this study, a new reservoir simulation model was developed based upon new/updated data. Two fluid PVT models (modified black oil and compositional) were also developed. At the start of the study, the operator felt that compositional formulation might be needed for modeling the gas injection processes. However, most of the work was performed using the modified black oil model because of computational speed consideration. The history match process showed that many simulation layers (grid blocks) were required to match the wells near the fluid contacts. Grouping some components in the compositional model was helpful to reduce run time, but the resulting equations of state (EOS) were generally not reliable for both the gas-cap and oil zones.Simulation results indicated that an OOIP of 98.5 MMSTB was required to obtain a good history match. The original free gas-in-place was estimated to be 210.1 BSCF. The best future development option was a booster compression project.For a 10-year prediction period, additional oil and gas recoveries for the booster compressor were predicted to be about 1.7% OOIP and 19.0% OGIP compared to the base case. Gas injection was less favorable because it would defer some volume of the gas sales, while water injection, workover and infill wells resulted in very small incremental oil and gas recoveries. The main reasons for the low oil recovery are high residual oil saturations estimated from core analyses, reservoir heterogeneity, and gas fingering from the large gas-cap.

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Section: Structural and Stratigraphic Settingmentioning

confidence: 99%

Section: Structural and Stratigraphic Settingmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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