Production optimization in mature field water drive gas reservoir is not easy especially when water already breakthrough in producing wells. An integrated reservoir study is needed to get reliable strategy to optimize production of water drive gas reservoir. This research presents the integrated reservoir study of Lower Menggala (LM) Gas Field which is located Central Sumatera Basin, Riau Province. LM had been produced since 1997, current RF are 55%, which is quite high for water drive gas reservoir. The current gas rate production is about 1.97 MMscfd with high water production around 4250 BWPD, consequently some of wells suffered liquid loading problem This research comprises of well performance analysis, estimate OGIP, aquifer strength of the reservoir by using conventional material balance method and modern production analysis method then conduct dynamic reservoir simulation to identify the best strategy to optimize gas production. Economic analysis also be performed to guide in making decision which scenario will be selected. DST analysis on DC-01 well defined reservoir parameter, boundary and deliverability which are P*= 2520 psia, k= 229 mD, Total skin= 8, detected sealing fault with distance 175 m, and AOF 45 MMscfd. Conventional material balance method gave OGIP 22.7 BScf, aquifer strength 34 B/D/Psi, whereas modern production analysis estimated OGIP 22.35 BScf, aquifer strength 34 B/D/psi. Those two method shows good consistency with OGIP volumetric calculation with discrepancy OGIP value +/- 1%. Six (6) scenario of production optimization has been analyzed, the result shows that work over in two wells and drilling of 1 infill well (case 6) achieve gas recovery factor up to 75.2%, minimal water production and attractive economic result
Rantau Field, located in the working area of PT. Pertamina EP, is considered as matured field. The field is located in North Sumatra, Indonesia. This field started producing in primary stage in 1930, and the secondary stage had been started in 1984 by injection of water. The water source comes from sea water with a salinity of 26000-33000 ppm. Since the injection of water quality is not good, then it had been damaged the injection wells, and it would automatically have an effect on the production wells. The oil production then started to decline.Pertamina EP EOR management team tries to increase the oil production back by implement re-secondary recovery process. The work started from field screening, study G&G, production analysis, preparing facility production, and follow up with a pattern pilot water flooding, and finally full scale project. Pilot water flooding kick off at layer Z-600 conducted in January 2010, Pertamina EP implemented a pilot water flooding in layer Z-600 block of C1 and C2 and managed to increase oil production from two wells (0 BOPD to 400-500 BOPD) and the reservoir pressure (from 155 Psi to 222.5 Psi in 3-month period conducted a pilot water flooding). With the success of pilot water flooding on the blocks C1 and C2, Pertamina EP will continue to full scale water flooding phases are planned to be carried out gradually in block A1 and A2. In addition to conducting secondary recovery, Pertamina EP will also plan for tertiary recovery phase for blocks/compartments that have been carried out secondary recovery activities. The production analysis is very important role in injection design, the scope include production and injection performance analysis, connectivity between injector and producer, pattern design and surveillance and monitoring.
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