High CO2 reservoir gas in Pertamina is considered as unconventional gas reservoir since the gas has low heating value. The high concentration of CO 2 in the gas caused the low heating. The gas need to be processed to make it marketable gas.A method to process high CO 2 gas content to an environmentally friendly fuel gas which can eliminate the possible climate change caused by CO 2 .Multi stage cryogenic process will separate CO 2 gas reservoirs using cryogenic reservoir stage step by step. The number of stage will be define the effective pressure and temperature of the vessel to separate the CO 2 from the gas reservoir. The Final goal is to obtain marketable gas which contain CO 2 less than 10%mol, heating value more than 1000 btu/Mscf.
Kenali Asam field, Pertamina EP working area, is located in West Sumatra of Indonesia. The field was discovered by NIAM in 1929. There are 285 wells were drilled which consist of 99 producing wells, 20 injector wells, and 8 dry well wells, and the rest are suspended wells. The reservoirs are layered reservoirs from shallow to deep zone, and 16 production zones. The oil was produced from primary stage to secondary stage. The secondary stage has been started by injecting water since March 1993. The water was injected to specific layer such as B/650, F/730, N/990, and S/1170. The peak production of primary recovery was 13,643 BOPD with water cut 14.4% in September 1954. Peak production of secondary recovery was 2105 BOPD with water cut 50% in October 1994.
TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThere is big change in
Most of oil fields managed by PT PERTAMINA (PERSERO) are considered as brownfields and the oil produced only from primary recovery stage. To get better recovery of oil in those brown fields, it is necessary to have a long term project such as Enhanced Oil Recovery (EOR). Some screening criteriahad been completed to selectappropriate method which could be applied in certain field. In this study, we presentgas injection program in West Java to obtain better recovery of the mature field/brownfield. The gas injection program include natural gas such as ethane, propaneand CO2 flooding. The viability relates mainly to the availability of CO2, the structure complexity, and finally the achievement of the Minimum Miscible Pressure (MMP).In the Jatibarang Field, it is not an issue of gas and CO2availability since gas and CO2 sources are available in the field itself, and near by fields. The Jatibarang Field primary recovery is only 16.2%, and the current reservoir pressure is as low as 500 psia. The reservoir performance shows the driving mechanism in this zone is very weak water influx.Therefore a Waterflood and/or EOR Program need to be evaluated to increase oil recovery. Based on the screening criteria for oil fields in West Java, there are several possible CO2 flood candidates, one of which is the Jatibarang Field.A fluid compatibility test was conducted using Jatibarang Field fluids, from current to initial conditions. The fluid properties of current and initial conditions were compared and analyzed using numerical simulation. Then an appropriate fluid model was selected to represent the reservoir conditions.Regression and fine-tuning of the equation of state resulted in the fluid characterization for this study.Tuning of the EOS should give a fluid model that closely matches the lab test results. Reservoir pressure is very important when it comes to designing gas and CO2 floods, as it is usually far below the MMP, as was the case in the Jatibarang Field.Based on the fine tuned fluid model, several gas and CO2 processes (immiscible and miscible flooding) were evaluated for the Jatibarang Field. These also included evaluation of different compositions of the natural gas and CO2 gas. The best tuning of EOS will give the fluid model that closely matches the lab test results.and then the fluid is applied to the compositional reservoir simulation. More than 25 alternatives of gas injection is studied using the compositional simulation. The best recovery is combination ofwater injection, CO2, ethane and propane flooding (% incremental oil recovery). Introduction Gas and CO2injection an reservoir oil has been widely used for the purpose of increasing oil recovery. Gas injection are used because of gas considered as non reactive gas, no needs special handling when the gas is produced with oil. Gas and CO2 flooding acts as an effective EOR method by reducing the remaining oil in the reservoir through several mechanisms (swelling, viscosity reduction, crude vaporization and miscible displacement). Most of the cases EOR is implemented after the primary recovery stage when the inner energy of the reservoir is not sufficient to produce the oil. The Jatibarang Field lies in the northwest Java Basin.It is located northwest of the city of Cirebon, West Java (Figure 1).Block III/Zone F of the Jatibarang Field has 31 wells. Currently, 12 wells are producing and 19 wells are inactive.The average reservoir depth is about 1140 m SS (3740' SS). The field is considered as mature field and production only from primary recovery.
<p>The East Java Gas Pipeline (EJGP) pipeline network system is an open access for transporting almost ± 310 MMSCFD of Natural Gas from fields in East Java offshore to the onshore Power Plant consumers. The deviation between the calculated and mass balance of gas stock is called the Discrepancy in which BPHMIGAS set up a maximum value of ± 0.85%. The objective of the study is to develop a verification methodology to support hydrocarbon accounting in the EJGP Pipeline Network System. The methodology will be assisted by Flow Quantity Assurance software. After obtaining sufficient data, a new baseline can be taken empirically which can be used as a reference for the maximum allowable discrepancy in the EJGP Pipeline Network System. The data used in this simulation are taken from September - October 2013 such as pipes dimension of the entire network piping system, flowrate, pressure, temperature, and the composition of natural gas. The results of verification are compared with the calculations carried out by Pertamina Gas as operators. The calculation of Discrepancy from the Operators with different tools is around 0.12%, meaning that operator calculations are acceptable. The maximum <br />allowable discrepancy ± 0.85%, can be reviewed to be reduced according to the history of the average system discrepancy in 2017-2018 (around 0.54%). The New Shipper from Sirasun Batur Field is still more economics by using the existing pipeline network even though it bears Discrepancy / Losses up to 1% compared to building new pipes to consumers. It is found that the discrepancy is getting smaller (reducing the error) if there is a gas balance, meaning that the end consumers will take the gas according to the agreed nomination.</p>
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