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Geological mapping include geomorphology, structural, stratigraphy of turbidite system, environmental geology and geological history analysis in Gegerbitung District, Sukabumi, West Java, Indonesia. The thesis based on the geological mapping work in the areal 6x9 (54) square kilometers. The geology of Gegerbitung District basically consist of turbidite system sediment deposited during Early-Middle Miocene with calcareous part at the base of the sequence and some volcanic impurities. The rocks was folded and faulted, especially due to Pliocene strike-slip fault in Sukabumi area.
The facies study intended to identify geometry of sand bodies on the undeveloped deeper producing reservoir section in Bekapai Field, Mahakam Basin, East Kalimantan, Indonesia. The base for study is the electric log data from Bekapai Field, operated by Total Indonesia. The study revealed the importance of electric log correlation to define the reservoir and marker continuity, also fluid distribution. The methodology found works in deltaic environment deposition setting which consist of sequence of sand-shale intercalation with sometimes a thin carbonate beds intercalation. The study conclude the depositional sequences based on electric log data and reveal the current process (wave, tidal, longshore drift and riverine) which control the sedimentation.
The purpose of this study is to roughly delineate the distribution of porosity and the control parameter in structural and stratigraphic sense. The study show that porosity and sand distribution closely related with depositional environment and structural setting. It is revealed that the porosity in Mutiara and Semberah fields controlled by structural setting (including depth) and depositional environment. The distributary sands give more porosity than interdistributary sands.
The field trip guide book intended to guide the one day trip to Gunung Walat are at 27 June 1992. The trip’s objective is to review Eocene Gunung Walat Sandstone which excellently exposed at Semen Cibinong quarry at Pasir Bongkok anticline comprise of complete section of fluvial-deltaic complex. The Batuasih marl (Late Oligocene) and Rajamandala limestone (Early Miocene) also put into observation.
The purpose of this project is to evaluate the reserves potential of reservoirs along the Nilam-Tambora Unit boundary. A total of 92 Nilam reservoir maps have been modified to incorporate Tambora well data. Based on the revised mapping, recoverable reserves in the reservoirs common to both Nilam and Tambora Units is estimated at 395.2 Bcf IGIP. This represents a 69.1 Bcf increase in IGIP over the previous map interpretations.
Abstract: An extensive depositional study supported by close spacing well was performed in the E67/E68/E69 reservoir series, which represents the most commercial reservoirs within "E" stratigraphic interval. The study documented a typical regressive / transgressive deltaic development sequence that controlled the reservoir distribution, quality and sand geometry in a river-dominated, tidally influenced deltaic setting. The interval represents a good example of typical delta lobe generation, development and extinction in the Middle Miocene fluvial-deltaic deposits of the western Kutai Basin, East Kalimantan.
Delta lobe generation was initiated by development of a widespread marine-prodelta shale characterized on logs by a very low resistivity signature. It was prograded by distributary mouth bar and distributary channel deposits of the E69 zone. Progradational delta lobe development continued in late E69 time with minor channel incisement, then reverted to an aggradational phase during subsequent relative sea level rise by backfilling of incised channel systems with E68 thick sand. This relative sea level rise was probably caused by subsidence, since a very high rate of sandy sediment influx continued during post-lowstand.
The delta lobe abandonment phase began with evidence of lowered riverine influx in the E67 zone, represented by a less extensive distributary channel system, abundant abandoned channel facies, and the westward migration (transgression) of the more distal deltaic facies such as distributary mouth bars. Delta lobe extinction is finally marked by extensive field-wide coal development, indicating an extended period of no clastic influx in this area.
The guide book describe the geology and outcrop geology of Jatiluhur Area, West Java, Indonesia. Jatiluhur area is the excellent outcrop example of Late Miocene Parigi Formation, which serve as major petroleum reservoir within North West Java basin. Parigi formation outcroppped continuously and excellently, consist of calcareous sandstone bad, sandstone, black shale and with a close look, we can see the facies change or differentiation. The ichno-fossil can be found elsewhere on Parigi and Cisubuh formation. The structural deformation can be seen with the dip changing dramatically until vertically stand.
The primary purpose of conducting a study of Nilam E67/68/69 sands was to characterize the reservoirs and evaluate the reservoir performance in terms of a. Reservoir Drive Mechanism, b. Future Production Profiles and c. Gas Recovery.
The Nilam E67/68/69 sands represent three successive depositional events that varied in rate of subsidence and sedimentation into the basin. These changes in sedimentation and subsidence produced variations in shape, areal extent, and thickness of individual sands reservoirs. The study used the well data which was compiled on cross sections, porosity/thickness plots, lithofacies, structure and net sand maps to interpret and generalize reservoir distribution patterns and to help identify additional drinage opportunities.
The E67/68/69 sands are composed of two major reservoirs and eight small reservoirs. Performance of the major reservoirs was evaluated using the SSI Workbench software and the reserves estimate of small reservoirs was made by using the Volumetric and Production Decline Analysis. A two-phase, three-dimensional areal model was set up for simulating the performance of E67/68/69 major reservoirs. The pressure performance of the major reservoirs was matched with Initial Gas In Place (IGIP) of 185 Bcf. The prediction runs indicated an ultimate gas recovery of 157 Bcf from the 4 producing wells and an additional 6 Bcf due to Nilam-3 successful workover. Combined IGIP and ultimate recovery for the major and small reservoirs are estimated to be 327 Bcf and 264 Bcf respectively. An abandonment rate of 0.5 MMcfd and 100 psi FTHP were assumed. Cumulative production was 112 Bcf as of October 31, 1994, leaving remaining reserves of 152 Bcf which, according to the model, would be recovered by 2018.
The salinity project was initiated to review the salinity to be used for petrophysical calculation. The source for the salinity value is derived from the apparent salinity from clean wet reservoirs that have thickness greater than 10 feet. This works include the database of 844 sands that meet the criteria for reliable apparent salinity computation. The resulted apparent salinity was used to calculate the Sw (water saturation) sensitivity to predict the calculated Sw based on new apparent salinity.
The thesis supervised by Dr. Purnomo Jusgiantoro, M.Sc, MBA (the assistant for Minister of Mining and Energy, Republic of Indonesia).
Abstract: The shift of world energy consumption centre to Asia Pacific is triggered by the area’s vast potential hydrocarbon resources. The Asian countries will be the major energy consumer at 2010 with 16.2 Tcf or 27% of the total world’s gas and oil consumption. Indonesia is a gas rich country need a mechanism to increase the efficiensy of investment evaluation on producing gas field’s asset and to understand the risk factor and estimated profit. The effort to develop marginal producing gas field can increase country’s gas production to supply domestic and export market, especially for domestic investor.
The development of gas industry need proper value assessment as a basis for investment decision making which include: asset acquisition, exploration and field development. The methodology of producing gas field’s asset valuation will be based on cash flow analysis for gas production forecast. The fair market value from producing gas field’s asset is ranging from 70-80% from net present value.
The sensitivity analysis was done to understand the impact of economic’s variable change which include: price, operation cost, working interest and discount factor. The gas price is the most sensitive varible for asset valuation. The portofolio analysis also performed and developed to understand the portofolio’s function and strength from each production unit. This analysis will give meaningful additional information for management strategy to develop gas producing field in the future. The asset valuation need to done by integrate cash flow analysis, sensitivity analysis and asset portofolio.
The general purpose of this report is to describe reservoir characterization and results of modelling in terms of a. Gas deliverability, b. Reserve estimates, and c. Future wells and workover requirement for efficient exploitation. The reservoir study resulted in identifying 33 Bcf of additional gas accumulations. Recommendations from this study include: 1. No further drilling is necessary to deplete the major reservoir which contains 67% of Nilam F-64 gas and 2. To accelerate future F-64.07 recompletions in the boundary wells to minimize Nilam depletion by Tambora wells.
The Nilam F-64 reservoir was deposited as one parasequence beginning with the F-66 low resistivity shale that grades upward to the F-64 sandstone. The sandstone development is finally topped with the N-20 coal. The F-64 reservoir accumulated in two major sand deposits. The most important one, located in the north-middle part of Nilam Field, is already severely depleted except in several isolated thick sand accumulations with no or partial depletion due to a stratigraphic permeability barrier from the main reservoir. In that hereto DeGolyer and McNaughton have not recognized these accumulations, some 33 Bcf of additional gas has been identified by this study.
This is intergrated report of gas resource assessment comprising of North Sumatra basin, Central Sumatra basin, Natuna basin and East Kalimantan basin. Also include the geological review of Meulaboh Block - offshore Northwest Sumatra, geology and hydrocarbon prospectivity of Waropen Block -North Irian Jaya, Ombilin inter-montane basin - onshore West Sumatra. Also special emphasize to Beringin Area - South Sumatra.
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The page last updated on 19 September 1996.
