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Tjuwati Makmur
Research and Development Centre for Oil and Gas Technology "LEMIGAS"
Chemical Engineering, Chemistry & Bioengineering Energy

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TESTS OF POLY ACRYLIC ACID (PPA) INHIBITOR ON BARIUM SULFATE SCALE INHIBITION EFFEICIENCY Tjuwati Makmur
Scientific Contributions Oil and Gas Vol 31 No 2 (2008)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.31.2.1004

Abstract

Injection water (containing sulphate ion) is injected into reservoir (containing barium ion), mixture of incompatible water types results in barium sulphate scale occurrence.
DETERMINATION OF PG12S SURFACTANT PHASE BEHAVIOUR IN THE MIXTURE OF OIL - SURFACTANT - COSURFACTANT - WATER Tjuwati Makmur; Nuraini Nuraini
Scientific Contributions Oil and Gas Vol 31 No 3 (2008)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.31.3.1013

Abstract

Surfactant is surface active agent chemical, while isopropyl alcohol (IPA) and also isobutyl alcohol (IBA) are known as cosurfactant and include types of alcohols used in enhanced oil recovery (surfactant flooding) method. Factors of surfactant, cosurfactant, and NaCl concentrations play important role in determination of phase behavior. Based on the results of phase behavior tests that the mixture of oil – PG12 surfactant – cosurfactant (IPA & IBA) – WIP water showed macroemulsion phase for all analyzed samples at different experimental conditions. PG12 surfactant is unable to be used for enhanced oil recovery by chemical injection, because it is very difficult to flow in porous media and to displace oil, because the occurrence of plugging which is caused by opaque and milky macroemulsion.
DETERMINATION OF OIL RECOVERY FACTOR BY USING WATER INJECTION-LABORATORY TEST METHOD Tjuwati Makmur
Scientific Contributions Oil and Gas Vol 28 No 1 (2005)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.28.1.1035

Abstract

Oil production limit that is usually followed by decrease of oil productivity in old fields is a major problem and can't be avoided. This case happened when cumulative oil production has approached primary recovery method. Decrease of the action of native reservoir energy is followed by drastically increase of production of water (saturation almost 100 %). In relation to this, a method is needed to obtain the additional oil recovery. Water injection method is one of the solutions to solve oil production problem that happened in old fields. It is expected that by using water injection method, productivity and oil recovery in old fields can be improved. Water that is used as the fluid injected into reservoir to improve oil recovery is sea water. How far oil recovery can be improved by using water injection method, is determined by a laboratory research. Before carrying out water injection laboratory test; one has to know what the main points that play important role in determining the optimal oil recovery by water injection method. These are: firstly, reservoir data, secondly, formation water and sea water analysis, thirdly, determination of physical fluid and rock properties, next, the displacement of water injection process to obtain the additional oil recovery and standard operational procedure. The main focus of this paper is "Determination of Oil Recovery Factor By Using Water Injection-Laboratory Test Method ". Hopefully, the contents of this paper give extremely valuable and useful information not only for LEMIGAS as Research and Development Centre for Oil and Gas Technology, but also for the oil industry or the Department of Petroleum Engineering of the universities in Indonesia.
DATA PREPARATION FOR WATER INJECTION LABORATORY TEST Tjuwati Makmur; Nuraini Nuraini
Scientific Contributions Oil and Gas Vol 27 No 1 (2004)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.27.1.1046

Abstract

Oil production limit that is usually followed by decrease of oil productivity in old fields is a major problem and can't be avoided. This case happened when cumulative oil production has approached primary recovery method. Decrease of the action of native reservoir energy is followed by drastically increase of production of water (saturation almost 100 %). In relation to this, a method is needed to obtain the additional oil recovery. Water injection method is one of the solutions to solve oil production problem that happened in old fields. It is expected that by using water injection method, productivity and oil recovery in old fields can be improved. Water that is used as the fluid injected into reservoir to improve oil recovery is sea water. How far oil recovery can be improved by using water injection method, is determined by a laboratory research. Before carrying out water injection laboratory test; one has to know what are the main points that play important role in determining the optimal oil recovery by water injection method. These are: firstly, basic parameters, secondly, laboratory test for water flooding, thirdly, the displacement of water injection process, then, standard operational procedure, next, water injection to obtain the additional oil recovey, lastly, the results are plotted a figure and or tabulated as the result of water injection laboratory test is obtained. In relation to the mentioned above, it will be better to write a scientific paper of water injection laboratory test. This paper is written based on our experience in enhanced oil recovery research (EOR), supported by textbook, such ás American Petroleum Institute, Petroleum Production Handbook and Standard Corrosion and water Technology For Petroleum Producers. Therefore, the main focus of this paper is "Data Preparation for Water Injection Laboratory Test". Hopefully, the contents of this paper give precious and useful informations, that is extremely valuable not only for LEMIGAS as Research and Development Centre for Oil and Gas technology, but also for the oil industry of the Departement of Petroleum Engineering of the universities in Indonesia
CALCIUM SULFATE SCALE IN THE PETROLEUM INDUSTRY Hadi Poernomo; Tjuwati Makmur
Scientific Contributions Oil and Gas Vol 27 No 1 (2004)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.27.1.1048

Abstract

Oilfield scale is defined as the precipitation of hard, adherent deposits of inorganic solid originating from aqueous media. This constitutes sulfate and carbonate of the alkaline earth metals calcium, barium and strontium and complex salts of iron. Generally, the process of the scale deposition occurs when the product solubility of a compound considered is exceeded. The formation of scale, such as calcium sulfate, has long recognised as one of the serious problems in oil and gas production leading to reduced production rates as flow becomes restricted. Calcium sulfate scale found in the oilfield is in the form of gypsum (CaSO4, 2H2,0) which is the most stable form at temperatures of 40 °C or less at atmosphere pressure. Above this temperature, anhydrite (CaSO4,) may be found, although hemihydrate (CaSO. 1/2H,O) may form under certain conditions. The reaction for precipitation of calcium sulfate is as follows: Ca+2 (aq) + so4-2 (aq) = CaSO4 (solid) The solubility of calcium sulfate in distilled water is 2080 mg/l at 25 "C. Calcium sulfate scale arises from several causes, such as temperature, dissolved salts, pressure, and time. The main points of this paper are focused on nomenclature, chemical structure, the occurrence of calcium sulfate scale, example of calcium sulfate scale in the petroleum industry, and calculation of calcium sulfate solubility in brine.
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)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.27.3.1054

Abstract

Laboratory and field studies indicate that almost every operation in the field, such as drilling, completion, workover, production and stimulation are potential source of damage to well productivity. Formation damage has long been recognized as a source of serious productivity reduction in many oil and gas reservoirs. The mud cake is a damage that occurs in formation caused by drilling process. Prevention of formation damage has the following advantages : a) To reduce ultimate completion costs; b) To preserve barriers; c) To improve sweep efficiency. Potassium chloride (KCI) and breaker are chemical materials used in mud clean up system to remove the mud cake formed in drilling process. In relation to this, it is very important to know whether the formation water and KCI solution, then the formation water and breaker, are compatible or not. This paper is written based on our experience in formation damage laboratory tests. Therefore, the main topic of this paper is "Test of Formation Water and Chemical Compatibility for Removal of Mudcake in Wellbore ". Hopefully, the laboratory test results presented in this paper are valuable, not only for LEMIGAS as Research and Development Centre For Oil and Gas Technology, but also for oil companies as the user which will apply the chemical material in oil fields (cost efficiency), chemical material supplier (particularly in design of breaker).
THE INFLUENCE OF ALCOHOL TYPE AND CONCENTRATION ON THE PHASE BEHAVIOR AND INTERFACIAL TENSION IN OIL-SURFACTANTCOSURFACTANT-BRINE MIXTURE SYSTEM Hadi Purnomo; Nuraini Nuraini; 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.27.2.1059

Abstract

The number of mechanism is limited for reducing the entrapment of oil in the pore space of reservoir rock and for mobilizing that residual which remains entrapped, thereby improving the microscopic displacement efficiency of a petroleum recovery process. After primary recovery by flow powered by the energy stored in the compressed fluids of reservoir, and secondary recovery by injection-pump driven water flooding, residual oil is trapped by the capillary pressure developed by interfacial tension in curved menisci between oil and water in the pore space. Figure 1.1 illustrates the interplay of capillary and viscous forces in the water flooding process. Shown in the figure is water displacing oil. The important point is that residual oil is trapped in the pore space by interfacial tension. To improve micros- copic displacement efficiency is to reduce interfacial tension between oil and water. Surfactant is surface active agent chemical that has two types of properties; lypofob (like water) and hydrofob (like oil). The value of interfacial tension between oil and water is high, when surfactant is dissolved into water and contacts with oil, so that surfactant is not only soluble in the water, but also it is soluble in the oil. By addition of surfactant into the water and contact with oil can result in interfacial tension between oil and water from high (more less 20 - 30 dyne/cm) to lower interfacial tension (10-2 dyne/cm). To change the lower interfacial tension to the lowest interfacial tension conditions (10-4dyne/cm), cosurfactant in oil-surfactant-brine mixture is used. Alcohols are widely used in micellar surfactant systems for enhanced petroleum recovery and are variously called cosurfactant or cosolvent. In general, alcohols modify the physico- chemical properties in ways that are important to the design of surfactant-based process for improving petroleum recovery. This research is focused on alcohol effects on oil-surfactant-brine phase behavior and interfacial tension of oil-surfactant-brine system.
DATA PREPARATION FOR AN ACCURATE ENHANCED OIL RECOVERY LABORATORY TEST BY USING SURFACTANT FLOODING METHOD Tjuwati Makmur
Scientific Contributions Oil and Gas Vol 28 No 2 (2005)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.28.2.1060

Abstract

In preparation of the study, x core plugs are drilled. Determination of basic parameter and identification of core plug sample are carried out following the API-RP 40. For example, the tests of physical properties, i.e. grain density (gr/cc), weight, grain volume (cc), pore volume (cc), posority (%), and air permeability (Ka.mD).
Co-Authors Hadi Poernomo Hadi Purnomo Nuraini Nuraini Panca Wahyudi