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Shale Hydrocarbon Development Based on Drill Cuttings &TOC Analysis: Case Study of Brownshale Drill Cuttings of Well BS-03, Pematang Formation, Bengkalis Trough, Central Sumatra Basin

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Open Journal of Yangtze Oil and Gas 2020年第3期5卷 87-102页

作者： Aris Buntoro Carolus Prasetyadi Ricky Adi Wibowo suranto Petroleum Engineering Department UPN “Veteran” Yogyakarta Indonesia India Geological Engineering Department UPN “Veteran” Yogyakarta Indonesia India Upstream Technical Center PT. Pertamina (Persero) Indonesia India

Brownshale is a lithology unit in the middle of the Pematang Formation consisting of brown to black shale that is deposited in the lacustrine environment. Brownshale from the results of previous studies stated as the main source rock in the Central Sumatra Basin, which is spread over several troughs, namely Balam, Aman, Rangau, Kiri, and Bengkalis Troughs, where Bengkalis Trough is the most extensive Trough. In the shale hydrocarbon prospecting analysis, Brownshale from previous researchers concluded that it had good prospects, based on several parameters including: TOC values with poor to very good quality. Brownshale formation is a type of kerogene as kerogen type of II/III, brittleness index greater than 0.48, and rock compressive strength below 10,000 Psi. One method in the development phase of shale hydrocarbon is to determine the fracable sweetspot window using drill cuttings and TOC, because there is no core data available. Based on the results of the well log analysis of well BS-03, it is obtained information that the Brownshale formation has a thickness of 1028 feet with intercalation laminated shale/sand section, so the mineral content varies greatly. From the ternary diagram of XRD (bulk analysis) results of drill cuttings of Brownshale formation of well BS-03, it can be seen that mineral distribution of Quartz-Clay-Calcite (Q-C-C) is spread between zone 1 to zone 3, namely: Dominant Quartz - Minor Clay & Carbonate (Zone 1: Brittle Quartz Rich), Dominant Carbonate - Quartz & Minor Clay (Zone 2: Brittle Carbonate Rich), and Quartz & Carbonate Balance - Clay minor (Zone 3: Ductile, hard to frac). This shows that not all Brownshale formation intervals are easy to frac (high fracability). From the XRD result, percentage of mineral content (bulk analysis) of Brownshale drill cuttings, there is an interesting phenomenon, i.e. the presence of sillimanite and kaliophilite minerals significantly starting at a depth of 10,780 ft and below, where both minera

关键词： Shale Hydrocarbon Mineralogy (XRD) Analysis TOC Analysis Fracability Model

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Preliminary Study by Reservoir Simulation of Field Trial Polymer Injection in SBR Field Using Silica-Modified HPAM

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Open Journal of Yangtze Oil and Gas 2020年第1期5卷 1-15页

作者： A. M. suranto Boni Swadesi Ratna Widyaningsih Retno Ringgani Department of Petroleum Engineering Universitas Pembangunan Nasional “Veteran” Yogyakarta Yogyakarta Indonesia Department of Chemical Engineering Universitas Pembangunan Nasional “Veteran” Yogyakarta Yogyakarta Indonesia

Polyacrylamide (PAM) is the most inorganic polymer type which is usually used in injection for enhanced oil recovery. Furthermore, hydrolyzed polyacrylamide (HPAM) is a common polymer used in polymer injection, but it has the sensitivity towards salinity and temperature. Thus, the experiment modified PAM and HPAM with silica aims to improve the performance of polymer toward temperature and salinity. This experiment included polymer synthesis, polymer modification, rheological measurement of the product and reservoir modeling study. Some experiments were performed to assess the feasibility of the product. In the polymer injection simulation, the properties of a polymer are referred to as product properties. The best outcome is selected to be implemented in SBR field. Prior to do trial in the real SBR field, the study by simulation is needed. The simulation predicts the incremental oil recovery and helps to determine an optimum injection rate and the best injection well location. The SBR field temperature, the salinity and the oil viscosity were about 60?C, 10,000 ppm and 2.64 cp, respectively. From the viscosity measurement, it was concluded that HPAM-Si was qualified to become a displacing agent because it had the highest viscosity among other product which was about 9.8 cp. The simulator used in this study was black oil IMEX-CMG simulator. The three scenarios applied were the base case, water injection and polymer injection. The base case gained recovery about 15.26%, whereas the water injection with a rate of about 2000 bbl/day gained oil recovery about 21.33%. The best scenario is polymer injection, where the optimum polymer injection rate is about 2000 bbl/day and the highest recovery is approximately 30.73%.

关键词： Polyacrylamide Silica Polymer Injection EOR

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