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All Journal Scientific Contributions Oil and Gas LEMBARAN PUBLIKASI MINYAK DAN GAS BUMI (LPMGB)
Tjuwati Makmur
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Chemical Engineering, Chemistry & Bioengineering Energy

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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)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.36.3.771

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
The Advantage Of Oil Content In Injection Water Determination Before Implementation Of Waterflood In Oilfield Tjuwati Makmur
Scientific Contributions Oil and Gas Vol 33 No 1 (2010)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.33.1.807

Abstract

Before implementation of water flooding in oilfield, it will be good to determine oil content in the injection water. The results of laboratory tests provide valuable and useful information, firstly, whether reverse demulsifier is required or not to reduce oil content in water. Secondly, the test results can select the effective reverse demulsifier. S1 and S2 injection water contain very low oil content, so it is not necessary to add reverse demulsifier in the both injection water. High oil content is obtained in S3 injection. The 50 mg/L DKM reverse demulsifier does not work effectively to reduce oil content in the S3 injection water. Whereas, the 50 mg/L Prolab reverse demulsifier is effective and able to reduce oil content sharply in the S3 injection water with 95.46 % efficiency.
Determination Of Asphaltene And C, H, N, O, S Contents In Crude Oil From X-Oilfield In South Sumatra Tjuwati Makmur
Scientific Contributions Oil and Gas Vol 32 No 2 (2009)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.32.2.840

Abstract

All analyzed crude oil samples contain firstly, the carbon contents in a range of 75.2830 % wt – 83.5739 % wt. Secondly, asphalthene with in a range of 0.6930 % wt – 1.8260 % wt and it can deposit in the formation and block the pore throats, which may reduce the permeability significantly. Thirdly, the hydrogen contents in a range of 9.1948 % wt –11.2339 % wt and it is impurities crude oil indicator. Fourthly, the crude oil samples have zero % wt nitrogen contents and don’t result in corrosive properties. However, the existence of the oxygen contents (in a range of 5.1634 % wt – 14.0560 % wt) and the sulfur contents (in a range of 0.1334 % wt – 0.2533 % wt) in the crude oil samples may cause corrosion problem.
The Influence Of Wet And Dry Seasons Conditions On Chemical Compositions, Properties And Total Suspended Solids Of Different Water Source And Type In Riau-Oil Fields Tjuwati Makmur; Nuraini Nuraini
Scientific Contributions Oil and Gas Vol 32 No 2 (2009)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.32.2.842

Abstract

Change of wet and dry seasons conditions have major impact, the results of chemical compositions concentration determination for RRV, RST, ORK, KWT, KWL and PRD water samples (sampling in dry seasons) are higher than in wet seasons. All of the analyzed water samples don’t results in the occurrence of calcium sulfate. Only PRD water has potential to form calcium carbonate scale, because pH value in a range of 7.85 – 8.10 (pH >7). The RRV, RST, ORK, KWT, KWL and PRD (sampling in wet and dry seasons) have poor injection water quality, because the concentrations of total suspended solids (TSS) in the analyzed water samples are higher than 8 ppm.
The Use Of Laboratory Tests To Study Oil Content In Injection Water Which Tend To Form Emulsion Block And Can Cause Plugging In Reservoir Rock Tjuwati Makmur
Scientific Contributions Oil and Gas Vol 31 No 1 (2008)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.31.1.858

Abstract

Oil content plays important role in determining injection water quality before the injection water is injected into reservoir for water flooding need. Determination of oil contents laboratory tests were carried out on five injection water samples from different gathering stations. The results of tests show that two of five injection water samples contain oil contents which fulfill MIGAS guidelines (25 ppm) requirements specification. Whereas, oil contents in the three injection water samples are in a range of 38.00 ppm and 77.00 ppm. The values of oil contents exceed MIGAS guidelines and tend to form emulsion block and cause the occurrence of plugging in reservoir rock.
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)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.27.2.873

Abstract

Water injection is often used to keep maintaining reservoir pressure. Injected water (high in sulphate) mixes with formation water (high in barium) leading to the deposition of barium sulfate scale in the near wellbore, reservoir, production tubulars and topside equipment. Barium sulfate scale is unique scale deposit and the least soluble of the scales. The deposition of oil field scale is a potentially damaging problem which reduces fluid flow resulting in a decline in oil production. The best approach to solving the problems of scale formation is to prevent or inhibit deposition and this is more effective than scale removal. The use of scale inhibitor can be effective method for preventing scalealthough their effectiveness is controlled by experimental conditions. Therefore, it is very important to know factors that influence barium sulfate scale. The maintopic of this paper is “The Influence of pH and Concentration of Inhibitor Solution - Tests on Change of Barium Sulfate Scale Morphology by Using Scanning Electron Microscope”. Hopefully, the results of laboratory test presented this paper give useful and valuable information not only for LEMIGAS, but also for oil industry, chemical manufacturers and universities, then other institutions.
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)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.30.3.975

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 (CaSO4) concentrations of S1, S2, S3 and S4 injection watersamples were in the range of 0.0208 to 0.4583 meq/l. While, the values of solubility ofS1, S2, S3 and S4 water samples at 77,145 and 1770F 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 S1, S2, S3 and S4 water samples at various temperature conditions(77,140 and 1750F) are higher than actual CaSO4 concentrations for the samewater samples. No occurrence of CaSO4 scale was found in all analyzed injection watersamples at different temperature conditions (77,140 and 1750F).
DETERMINATION OF TOTAL BACTERIA COUNT AND SELECTION OF INJECTION WATER QUALITY RATING CHART FOR WATER FLOOD NEEDS IN SUMATRA OIL FIELDS Nuraini Nuraini; Tjuwati Makmur
Scientific Contributions Oil and Gas Vol 30 No 3 (2007)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.30.3.978

Abstract

An important factor affecting the success of a water flood project for secondary recoveryis the quality of the water being injected. In this research, the water quality tests werefocused on determination of total bacteria counts of the analyzed injection water sampleusing ASTM D 5465-93 and selections of injection water quality rating chart for waterflood needs in Sumatra oil fields. The results of microbiological laboratory tests of allanalyzed injection water samples showed three parts. An injection water sample of N - 82containing type of bacteria Bacillus sp with the total bacteria counts 5.02 x 100 colonies/ccwas categorized as no. 1 water quality rating chart. Subsequently, G – GS injection watersample indicated Bacillus sp with total bacteria counts 4.28 x 101 colonies/cc and BacillusLaterosporous with total bacteria count 3.31 x 101 colonies/cc for G – 90 water sample.Two samples mentioned above were classified as no. 2 water quality rating chart. Next,Bacillus Alvei was found in T – 21 injection water sample with total bacteria count 1.85 x102 colonies/cc and Bacillus Pathothenticus in T – GS injection water samples with totalbacteria count 2.61 x 102 colonies/cc. Position of water quality rating chart for both lastsamples were no. 3. These results gave valuable and useful information before implementationof water flood in the oilfield.
PENINGKATAN PEROLEHAN MINYAK DENGAN METODE INJEKSI SURFAKTAN PETROLEUM SULFONAT SECARA SKLA LABORATORIUM Tjuwati Makmur
Lembaran publikasi minyak dan gas bumi Vol 39 No 1 (2005)
Publisher : BBPMGB LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/LPMGB.39.1.657

Abstract

Surfactant Flooding melakukan salah satu cara untuk menurunkan sisa minyak yang tertinggal didalam reservoir dengan jalan menginjeksikan suatu zat aktif permukaan minyak-air. dengan turunnya tegangan antar muka maka gaya kapiler pada daerah penyempitan pori-pori dapat dikurangi, sehingga sisa minyak yang terperangkap didalam pori-pori dapat dikurangi, sehingga sisa minyak yang terperangkap di pori-pori dapat didesak dan diproduksikan.
Pengaruh pH, Temperatur dan Waktu Kontak terhadap Efisiensi Pencegahan Kerak Barium Sulfat dengan Menggunakan Inhibitor DETPMP Tjuwati Makmur
Lembaran publikasi minyak dan gas bumi Vol 39 No 2 (2005)
Publisher : BBPMGB LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/LPMGB.39.2.733

Abstract

Singkapan sedimen umur Paleogen yang terdapat di Indonesia Barat sangat terbatas jumlahnya. Hal ini terutama disebabkan oleh aktivitas tektonik yang intensif yang berlangsung bersamaan dan sesudah umur Paleogen, yang mengakibatkan formasi umur ini tertimbun jauh di bawah permukaan. Sedangkan sedimen Paleogen yang didapat dari pemboran eksplorasi sulit diperoleh karena bersifat rahasia. Oleh karena itu tidak mengherankan kalau penelitian palinologi terhadap sedimen umur ini masih terbatas jumlahnya. Meskipun demikian, gambaran umum palinologi umur Paleogen sedikit banyak sudah terungkap. Sebagai buktinya beberapa peneliti telah menyusun zonasi polen untuk umur Paleogen seperti Morley (1991) dan Rahardjo dkk. (1994). Penelitian paling lengkap terhadap sedimen Paleogen tertua dilakukan oleh Muller (1968) terhadap Formasi Kayan (dulu bernama Plateau Sandstone) berumur Paleosen- Eosen Awal yang tersingkap di Sarawak. Keragaman polen dari formasi ini rendah dibandingkan dengan keragaman polen masa kini yang ada di Dataran Sunda dan umumnya tidak mempunyai kesamaan dengan spesies modern. Di antara sedimen Paleogen yang paling kaya dengan kandungan palinomorf adalah Formasi Nanggulan berumur Eosen Tengah-Akhir yang tersingkap di desa Nanggulan, D. I. Yogyakarta. Beberapa penelitian dilakukan pada formasi ini antara lain oleh Barton (1988), Morley dan Harley (1995), dan Lelono (2000). Keragaman dan kelimpahan polen pada Formasi Nanggulan sangat tinggi terutama pada sedimen umur Eosen Tengah menunjukkan kondisi iklim basah tropis yang memungkinkan terbentuknya hutan tropis yang lebat. Selain itu, penelitian yang telah dilakukan memperlihatkan kehadiran palinomorf yang berasal dari India. Hal ini membuktikan bahwa telah terjadi migrasi tumbuhan dari India ke wilayah Asia Tenggara karena menyatunya kedua daerah tersebut
Co-Authors Hadi Purnomo Nuraini Nuraini Nuraini Panca Wahyudi Sugihardjo Sugihardjo Supnyatno