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All Journal Scientific Contribution Oil and Gas LEMBARAN PUBLIKASI MINYAK DAN GAS BUMI
Tjuwati Makmur
Unknown Affiliation
Chemical Engineering, Chemistry & Bioengineering Earth & Planetary Sciences Energy Engineering Environmental Science

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Influence Of Activated Carbon On Total Suspended Solids And Relative Plugging Index Of Injection Water From X-Oilfield Tjuwati Makmur
Scientific Contributions Oil and Gas Vol. 36 No. 3 (2013): SCOG
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.36.3.19

Abstract

Produced water will be used as injection water for water flooding need, but, based on the results of water quality tests show poor injection water quality caused by a lot of solids particles with high total suspended solids (TSS) concentration and high relative plugging index (RPI) obtained in the injection water. When, the condition of injection water without treatment is injected into formation will cause serious plugging. In this study, two methods used to minimize the high TSS and RPI problems are treatment with chemical and filtration (activated carbon). The use of optimal concentration of scale inhibitor in the injection water can reduce TSS and RPI in the injection water, but it does not work effectively, so that its water quality is still poor water quality and can cause plugging in the formation. Another method is filtration with activated carbon filter media which has characteristics of adsorption and large specific area to filter insoluble materials in the injection water. After filtration, the filtrate of the injection water results in clear water condition. Based on the results of laboratory tests indicate that the filtrate of the injection water contains the least solids particles with small particle size, low total suspended solids concentration and low relative plugging index value. When, it is injected into formation, the possibility of plugging occurrence can be minimized, although, there is increase of pH value, but, in general, the filtrate of the injection water can be categorized good water quality
DATA PREPARATION FOR WATER INJECTION LABORATORY TESI Tjuwati Makmur; Nuraini Nuraini
Scientific Contributions Oil and Gas Vol. 27 No. 1 (2004): SCOG
Publisher : Testing Center for Oil and Gas LEMIGAS

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Abstract

Oil production limit that is usually followed by de-crease of’oil productivity in old fields is a major problemand can’t be avoided. This case happened when cumu-lative oil production has approached primary recoverymethod. Dccrease of the aetion of native reservoir en-ergy is followed by drastically increase of production ofwater (saturation almost 100 %).
CALCIUM SULFATE SCALE IN THE PETROLEUM INDUSTRY Hadi Purnomo; Tjuwati Makmur
Scientific Contributions Oil and Gas Vol. 27 No. 1 (2004): SCOG
Publisher : Testing Center for Oil and Gas LEMIGAS

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Abstract

Oilfield scale is defined as the precipitation of hard,adherent deposits of inorganic solid originating from aque-ous media. This constitutes sulfate and carbonate of thealkaline earth metals calcium, barium and strontium andcomplex salts of iron. Generally, the process of the scaledeposition occurs when the product solubility of acom-pound considered is exceeded. The formation of scale,such as calcium sulfate, has long recognised as one ofthe serious problems in oil and gas production leading toreduced production rates as flow becomes restricted.
THE INFLUENCE OF pH AND CONCENTRATION OF PHOSPHONATE INHIBITOR - TESTS ON CHANGE OF BARIUM SULFATE SCALE MORPHOLOGY BY USING SCANNING ELECTRON MICROSCOPE Tjuwati Makmur
Scientific Contributions Oil and Gas Vol. 27 No. 2 (2004): SCOG
Publisher : Testing Center for Oil and Gas LEMIGAS

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Abstract

Water injection is often used to keep maintainingreservoir pressure. Injected water (high in sulphate) mixeswith formation water (high in barium) leading to the depo-sition of barium sulfate scale in the near wellbore, reser-voir, production tubulars and topside equipment. Bariumsulfate scale is unique scale deposit and the least solubleof the scales. The deposition of oil field scale is a poten-tially damaging problem which reduces fluid flow result-ing in a decline in oil production.
THE INFLUENCE OF ALCOHOL TYPE AND CONCENTRATION ON THE PHASE BEHAVIOR AND INTERFACIAL TENSION IN OIL-SURFACTANT- COSURFACTANT-BRINE MIXTURE SYSTEM Hadi Purnomo; Nuraini Nuraini; Tjuwati Makmur
Scientific Contributions Oil and Gas Vol. 27 No. 2 (2004): SCOG
Publisher : Testing Center for Oil and Gas LEMIGAS

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Abstract

The number of mechanism is limited for reducingthe entrapment of oil in the pore space of reservoir rockand for mobilizing that residual which remains entrapped,thereby improving the microscopic displacement effi-ciency of a petroleum recovery process. After primaryrecovery by flow powered by the energy stored in thecompressed fluids of reservoir, and secondary recoveryby injection-pump driven water flooding, residual oil istrapped by the capillary pressure developed by interfa-cial tension in curved menisci between oil and water inthe pore space. Figure 1.1 illustrates the interplay ofcapillary and viscous forces in the water flooding pro-cess. Shown in the figure is water displacing oil. Theimportant point is that residual oil is trapped in the porespace by interfacial tension. To improve micros- copicdisplacement efficiency is to reduce interfacial tensionbetween oil and water.
Determination Of Pg12s Surfactant Phase Behaviourin The Mixture Of Oil - Surfactant - Cosurfactant - Water Tjuwati Makmur; Nuraini
Scientific Contributions Oil and Gas Vol. 31 No. 3 (2008): SCOG
Publisher : Testing Center for Oil and Gas LEMIGAS

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Abstract

Surfactant is surface active agent Chemical, -while isopropyl alcohol (IPA) and alsoisobutyl alcohol (IBA) are known as cosurfactant and include types of alcohols used inenhanced oil recovery (surfactant flooding) rnethod. Factors of surfactant, cosurfactant,and NaCl concentrations play important role in determination of phase behavior. Basedon the results of phase behavior tests that the mixture of oil - PG12 surfactant - cosurfac-tant (IPA & IBA) - WIP water showed macroemulsion phase for all analy.ed samples atdifferent experimental conditions. PG12 surfactant is unable to be used for enhanced oilrecovery by Chemical injection, because it is very difficult to flow in porous media and todisplace oil, because the occurrence of plugging which is caused by opaque and milkymacroemulsion.
Tests Of Poly Acrylic Acid (Paa) Inhibitor On Barium Sulfate Scaleinhibition Efficiency Tjuwati Makmur
Scientific Contributions Oil and Gas Vol. 31 No. 2 (2008): SCOG
Publisher : Testing Center for Oil and Gas LEMIGAS

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Abstract

Injection water (containing sulfate ion) is injected into reservoir (containing bariumion), mi.vture of incompatible water types results in barium sulfate scale occurrence. Bariumsulfate scale inhibition efficiency (%) with using poly acrylic acid (PAA) inhibitor wereconducted in e.sperimental conditions. pH (2.0, 4.0. 5.5, 7.0) 5 and 10 ppm inhibitor con-centrations. and 25 and 70 "C temperatures. AU laboratory tests results data show effi-ciency (%) value less than 50 %, except at pH 7.0 and 70 "C conditions which has a littlehit higher efficiency (55.28 %). The poly acrylic acid doesn't show a good t/uality inhibi-tor, because the occurrence of barium sulfate scale can not he inhihited effectively.
TEST OF FORMATION WATER AND CHEMICAL COMPATIBILITY FOR REMOVAL OF MUDCAKE IN WELLBORE Panca Wahyudi; Tjuwati Makmur
Scientific Contributions Oil and Gas Vol. 27 No. 3 (2004): SCOG
Publisher : Testing Center for Oil and Gas LEMIGAS

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Abstract

Laboratory and field studies indicate that almostevery operation in the field, such as drilling, completion,workover, production and stimulation are potential sourceof damage to well productivity. Formation damage haslong been recognized as a source of serious productivityreduction in many oil and gas reservoirs. The mud cakeis a damage that occurs in formation caused by drillingprocess. Prevention of formation damage has the fol-lowing advantages: a) To reduce ultimate comple-tion costs; b) To preserve barriers; c) To improvesweep efficiency.
DETERMINATION OF OIL RECOVERY FACTOR BY USING WATER INJECTION-LABORATORY TEST METHOD Tjuwati Makmur
Scientific Contributions Oil and Gas Vol. 28 No. 1 (2005): SCOG
Publisher : Testing Center for Oil and Gas LEMIGAS

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Abstract

Oil production limit that is usually followed by de-crease of oil productivity in old fields is a major problemand can't be avoided. This case happened when cumu-lative oil production has approached primary recoverymethod. Decrease of the action of native reservoir en-ergy is followed by drastically increase of production ofwater (saturation almost 100 %).
STUDY OF CALCIUM SULFATE SCALING INDEX TENDENCY CALCULATIONS AT DIFFERENT TEMPERATURE CONDITIONS IN INJECTION WATER SAMPLES FROM OILFIELDS Tjuwati Makmur
Scientific Contributions Oil and Gas Vol. 30 No. 3 (2007): SCOG
Publisher : Testing Center for Oil and Gas LEMIGAS

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Abstract

Calcium sulfate scale is a type of scale found in petroleum industry and shows seriousproblem, because it can plug pore media and cause a decrease in production rate. Actual calcium sulfate (CaSO j concentrations ofSl, S2, S3 and S4 injection watersamples were in the range of 0.0208 to 0.4583 meq/l. While, the values of solubility ofSI, S2, S3 and S4 water samples at 77,145 and 177°F are in a range of 23.20 to 27.43meq/l. Based on the results of calcium sulfate scaling tendency calculations showed thatthe values of solubility of SI, S2, S3 and S4 water samples at various temperature condi-tions (77,140 and 175°F) are higher than actual CaSO4 concentrations for the sarne■water samples. No occurrence of CaSO4 scale was found in all analy.ed injection watersamples at different temperature conditions (77,140 and 175°F). Key words : calcium sulfate scale, scaling index tendency calculation, solubility of injec-tion water sample and actual CaSO4 concentration.
Co-Authors Hadi Purnomo Nuraini Nuraini Nuraini Panca Wahyudi Sugihardjo Sugihardjo Supnyatno