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<![CDATA[A SYSTEMATIC APPROACH TO SOURCE-SINK MATCHING FOR CO2 EOR AND SEQUESTRATION ]]>
<![CDATA[Usman Pasarai]]>;
<![CDATA[Utomo Pratama Iskandar]]>;
<![CDATA[Sugihardjo Sugihardjo]]>;
<![CDATA[Herru Lastiadi S]]>
<![CDATA[ Scientific Contributions Oil and Gas Vol 36 No 1 (2013) ]]>
Publisher : <![CDATA[Testing Center for Oil and Gas LEMIGAS ]]>
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DOI: 10.29017/SCOG.36.1.640
<![CDATA[Carbon dioxide for enhanced oil recovery (CO2 EOR) can magnify oil production substantially while aconsistent amount of the CO2 injected remains sequestrated in the reservoir, which is benefi cial for reducingthe greenhouse gas (GHG) emission. The success of CO2 EOR sequestration depends on the proper sourcessinksintegration. This paper presents a systematic approach to pairing the CO2 captured from industrialactivities with oil reservoirs in South Sumatra basin for pilot project. Inventories of CO2 sources and oilreservoirs were done through survey and data questionnaires. The process of sources-sinks matching waspreceded by scoring and ranking of sources and sinks using criteria specifi cally developed for CO2 EORand sequestration. The top candidate of CO2 sources are matched to several best sinks that correspond toadded value, timing, injectivity, containment, and proximity. Two possible scenarios emerge for the initialpilot where the CO2 will be supplied from the gas gathering station (GGS) while the H3 and F21 oil fi eldsas the sinks. The pilot is intended to facilitate further commercial deployment of CO2 EOR sequestrationin the South Sumatera basin that was confi rmed has abundant EOR and storage sinks as well as industrialCO2 sources.]]>
<![CDATA[A Study of Spontaneous Imbibition Recovery Mechanism of Surfactant Formulated from Methyl Ester Sulfonates ]]>
<![CDATA[Sugihardjo Sugihardjo]]>
<![CDATA[ Scientific Contributions Oil and Gas Vol 36 No 2 (2013) ]]>
Publisher : <![CDATA[Testing Center for Oil and Gas LEMIGAS ]]>
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DOI: 10.29017/SCOG.36.2.763
<![CDATA[MES (Methyl Ester Suffocates) can be formulated to become surfactant-MES that has surfactant potential properties for EOR (enhanced oil recovery). A such formulated surfactant MES by adding some solvents and chemicals to adjust its properties in order to generate a compatibity with reservoir fluid and rock has been developed. This formulated surfactant MES, therefore, has been tested its properties for enhanced oil recovery in a selected oil field. The oil field produces an oil withc39.45oAPI, and brine content of about 18,900 mg/L equivalent NaCl concentration. While reservoir rock is not available and substituted by Bentheimer standard core. Basically the production enhancements of surfactant solution for EOR processes are wettability alteration and interfacial tension reduction. In these experiments, some evaluations have been done to observe the capability the formulated surfactant MES for oil production enhancements includingwettability alteration and imbibition capability. Formulated low interfacial tension surfactant-MES that will be evaluated for spontaneous imbibition ability have been diluted in the brine of 0.5 and 1.0% concentrations. Tests on wettability alteration indicated that the surfactant solutions could not change the wettability of the rocks. The initial wettability is mixed wet and still mixed wet after ageing in the surfactant solution. On other hand the spontaneous imbibition tests resulted in significant oil production coming out from the cores, i.e. 67.07% oil recovery with 0.5% surfactant and 92.25% for 1.0% surfactant solutions. But optimum oil recovery factor by brine imbibition is only 41.69%]]>
<![CDATA[Preliminary Carbon Untilization And Storage Screening Of Oil Fields In South Sumatra Basin ]]>
<![CDATA[Sugihardjo Sugihardjo]]>;
<![CDATA[Usman Usman]]>;
<![CDATA[Edward ML Tobing]]>
<![CDATA[ Scientific Contributions Oil and Gas Vol 35 No 2 (2012) ]]>
Publisher : <![CDATA[Testing Center for Oil and Gas LEMIGAS ]]>
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DOI: 10.29017/SCOG.35.2.778
<![CDATA[Carbon utilization in oil fi elds as EOR project has becomes main issue nowdays. Therefore preliminary CO2-EOR screening has been done for the oil fi elds laid on South Sumatra Basin, where CO2 emission arise from a number different sources of activities in South Sumatra area. Around 103 oil fi elds and consisting 581 reservoirs have been analysis to select which of those fi elds fulfi ll CO2 injection criteria. The criteria applied of the selection are based on EOR Screening Criteria Revisited papers introducing by J.J Taber at. All. 1977. The results of the screening are categorized as miscible, immiscible and failed for CO2 injection. Afterward, CO2 storage and incremental oil recovery due to CO2 injection were calculated using equation normally used in the oil industries. The incremental oil recovery due to CO2-EOR has been assumed as high as 12% of OOIP at miscible process and only 5% for immiscible displacement. The calculation of CO2 storage is based on the ultimate primary recovery for each fi eld in addition of the additional recovery due to CO2-EOR. Both primary and tertiary recovery have been used as the basic of calculating the CO2 storage. The results of the screening whether reservoir categories in immiscible, miscible injection and failed to fulfi ll EOR-CO2 injection criteria can be summarized as follow: 18 fi elds immiscible, 77 miscible, and 7 failed. Total incremental oil recovery estimate from CO2-EOR is approximately 480.5 MMSTB. While the total CO2 storages estimate are about 70 MMton for voidage replacement due to production at ultimate recovery and 22 MMton at EOR-recovery, so the total CO2 storage is approximately 92 MMton.]]>
<![CDATA[Polymer Properties Determination For Designing Chemical Flooding ]]>
<![CDATA[Sugihardjo Sugihardjo]]>
<![CDATA[ Scientific Contributions Oil and Gas Vol 34 No 2 (2011) ]]>
Publisher : <![CDATA[Testing Center for Oil and Gas LEMIGAS ]]>
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DOI: 10.29017/SCOG.34.2.799
<![CDATA[Waterflooding became the standard practice in many reservoirs formation in petroleum industries, the strengths and weaknesses of the methods were quite well established. In particular, the inefficiency of the waterflood oil displacement mechanism as a result of either an unfavorable mobility ratio or heterogeneity was largely identified. Therefore, chemicals injections as the improvement displacement processes had been proposed to support petroleum industries to recover the production of oil. Chemical injection normally consists of alkaline, surfactant, and polymer (ASP). They could be injected as standalone fluid or mixture of fluids; it depends upon the injection fluid design appropriate for particular field. Polymer solution could be prepared for mixtures of injection fluid and or as chase fluid injection which is injected behind surfactant or ASP. The main function of polymer solution primarily is to viscosity the injection water as a mobility control. This work is proposed to determine the important polymer properties which are suitable for mobility control in such EOR plan in the particular field. This field is sandstone reservoir with oil gravity of 23 to 26oAPI and viscosity of 3cp at 90oC. Two kinds of polymers have been chosen such as: HPAM-1 and HPAM-2 and subject to be tested for the properties characteristic. Intensive works have been done to evaluate the bulk polymer properties at laboratory scale which include rheology, filtration, thermal stability, retention/adsorption, and injectivity or permeability reduction tests. The results indicated that HPAM-1 polymer is suitable for injection fluid design for Zone-B while HPAM-2 for Zone-A.]]>
<![CDATA[Tracer Tests For Heterogeneity Characterization And Saturation Determination On Core Flooding ]]>
<![CDATA[Sugihardjo Sugihardjo]]>;
<![CDATA[Usman Usman]]>;
<![CDATA[Utomo Pratama I]]>
<![CDATA[ Scientific Contributions Oil and Gas Vol 33 No 3 (2010) ]]>
Publisher : <![CDATA[Testing Center for Oil and Gas LEMIGAS ]]>
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DOI: 10.29017/SCOG.33.3.821
<![CDATA[Low sweep efficiency is the common problem in displacement process due to heterogeneity, high permeability streaks, fractures, and thief zones existing in the formation. Similarly, the success or failure of EOR implementations are always affected by those problems which causes displacing fluids fingering and early breakthrough. Factors of this type, unless properly identified and understood before the start of EOR process, will likely cause a project failure. Core flooding as the model of small scale of fluids movements in reservoir undergoes similar circumstances. Approximately one foot long of four 3.5 inches stacked native and synthetic cores are normally used in core flooding experiment. Tracer test was performed to characterize the core in addition of CT scan analysis. On this experiment, lithium solution was selected as tracer solution to be then injected into core at constant rate, 4 ft/day. Afterwards, the effluents were collected by Gilson sample collector in each tube for further determinination its concentration using Atomic Absorption Spectrometry (AAS). Response curves of lithium tracer were able to determine core heterogeneities and this should be done to avoid misleading interpretation of core flooding results. Besides, lithium concentration reported in some extent and subsequently analyzed by employing method of temporal moments. This method provides numerical calculation to estimate effective core pore volume (PV) and fluid saturation. Weighing method was also used to compare the PV with aforementioned method and the results were comparable.]]>
<![CDATA[Capillary Desaturation Curves For Evaluating Surfactant Performance By Core Flooding Experiments ]]>
<![CDATA[Sugihardjo Sugihardjo]]>
<![CDATA[ Scientific Contributions Oil and Gas Vol 32 No 1 (2009) ]]>
Publisher : <![CDATA[Testing Center for Oil and Gas LEMIGAS ]]>
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DOI: 10.29017/SCOG.32.1.828
<![CDATA[Capillary desaturation curves are normally generated in laboratory scale by means of core flooding experiments to evaluate the surfactant formulations for chemical injection in EOR projects. Low tension surfactant solution is the only liquid that could increase the dimensionless capillary number in order of magnitude of 103. Two types of core samples have been used in core flooding experiments to develop capillary desaturation curves, i.e., generic and standard Classhach core samples. In Addition, VS surfactant and additional alcohols are also used in these experiments. The higher the capillary number could generate a lower the residual oil saturation. Moreover, each rock may have a particular capillary desaturation curve depending on the rock properties. Therefore before implementing chemical injection in a pilot scale, capillary desaturation curve should be developed in laboratory to evaluate the surfactant injection performance.]]>
<![CDATA[Surfactant-Induced Wettability Alteration ]]>
<![CDATA[Sugihardjo Sugihardjo]]>
<![CDATA[ Scientific Contributions Oil and Gas Vol 32 No 1 (2009) ]]>
Publisher : <![CDATA[Testing Center for Oil and Gas LEMIGAS ]]>
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DOI: 10.29017/SCOG.32.1.834
<![CDATA[Contact of surfactant solution onto rock surface has an important impact on the wettability alteration of the rock. This phenomenon has widely received attention of researchers on the field of EOR (enhanced oil recovery), at which surfactant solution basically has been used as the main injection fluid. However, there has not yet come up with conclusive findings, which is due to the unique characteristics of surfactant used at the oil fields. Therefore, every surfactant needs a particular laboratory evaluation before injected into a reservoir. We have evaluated surfactant-induced wettability alteration by means of contact angle measurement. Three kinds of surfactant have been used in this experiment, namely: TFSA (thin film spreading agent), IFT-R (interfacial tension reduction), and Well Stimulator type of surfactants. Two kinds of rocks namely LS (limestone) and SL (sandy limestone) have also been prepared. Both rocks are originally oil wet. TFSA-LS interaction tend to decrease the oil preferences with time, the contact angle increased 30 degrees after 8 weeks. Whereas TFSA-SL experienced only a little change of contact angle. Contact IFT-R and LS has changed significantly the contact angle to around 51degrees indicating less oil preference. Whereas, IFT-R and SL only changed a bit to less oil wet. The stimulator type of surfactant obviously lessen the oil wet tendency for the both rocks, the contact angles increase from initially around 15 to 35 degrees. In this experiment we found out that all the three surfactants generally tend to change the wettabillity to less oil wet.]]>
<![CDATA[Interfacial Tension Between Injecting Fluid And Reservoir Oil At Elevated Pressure And Temperature ]]>
<![CDATA[Sugihardjo Sugihardjo]]>
<![CDATA[ Scientific Contributions Oil and Gas Vol 30 No 1 (2007) ]]>
Publisher : <![CDATA[Testing Center for Oil and Gas LEMIGAS ]]>
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DOI: 10.29017/SCOG.30.1.863
<![CDATA[An important parameter of surfactant flooding in enhanced oil recovery (EOR) processes is the interfacial tension (IFT) reduction between the injecting fluid and the reservoir oil. To measure the IFT precisely and accurately at high pressure and temperature, Pendant Drop Apparatus had been set up. IFT between surfactant solution and reservoir oil have been investigated at several different pressure and temperature. The working pressure ranged from 0 psig up to 5000 psig, and the temperature varied from ambient condition to 80oC. The results indicated that the interfacial tension behavior of surfactant solution and reservoir oil was very unique characteristics as the pressure and temperature increase. However, some conclusion can be withdrawn from these experiments. Increasing pressure causes relatively minor change in IFT. On the other hand the rise of temperature tended to raise the IFT much more significant. Since the surfactant solution having unique behavior therefore it is recommended that IFT must be measured in laboratory at the reservoir condition before injecting in to a reservoir.]]>
<![CDATA[Development Of Waterflood Profile Modification Using Brightwater Technology ]]>
<![CDATA[Sugihardjo Sugihardjo]]>
<![CDATA[ Scientific Contributions Oil and Gas Vol 28 No 3 (2005) ]]>
Publisher : <![CDATA[Testing Center for Oil and Gas LEMIGAS ]]>
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DOI: 10.29017/SCOG.28.3.871
<![CDATA[Water flooding, in many mature fields is facing a common problem of low sweep efficiency in the late production period. The breakthrough of injection water is very early when high permeability streaks or thief zones exist in the formation, and resulted in excessive water production. Two kind of technologies commonly are used to modify the permeability streak i.e. MPM (Microbial Profile Modification), and polymer gel with cross linkers material. A new technology which is called Bright Water has been intensively studied. Bright Water is capable of in-depth placement into high permeability streaks in the reservoir. To improve the water flood sweep efficiency, studies of examination a fluid injection design have been evaluated. The objective of this study is to set-up core flooding tests and to determine the effective- ness of the Bright Water to reduce the permeability, and also include optimization of Bright Water formulation, resistance factor determination, and gelling time evaluation.]]>
