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Scientific Contributions Oil and Gas
Published by LEMIGAS
ISSN : 20893361     EISSN : 25410520     DOI : -
Core Subject : Science, Engineering,
Chemical Engineering, Chemistry & Bioengineering Energy
The Scientific Contributions for Oil and Gas is the official journal of the Testing Center for Oil and Gas LEMIGAS for the dissemination of information on research activities, technology engineering development and laboratory testing in the oil and gas field. Manuscripts in English are accepted from all in any institutions, college and industry oil and gas throughout the country and overseas.
Arjuna Subject : Energi (semua kategori) - Teknologi Bahan Bakar
Articles 9 Documents
 1 
Search results for , issue "Vol 33 No 1 (2010)" : 9 Documents clear
Single or Multiple Porosity Cut Off A New Relevance Provided By Application of A New Approach Bambang Widarsono
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.33.1.643

Abstract

Porosity cut-off is one of the most important parameter normally used to differentiatebetween reservoir and non-reservoir rocks. Quantity of the parameter certainly dictatesreservoir volumes, hence directly influences economics and commerciality of a given oil/gas field. An ever critical issue in relation to this parameter is whether the use of porositycut-off has to be established through a single or multiple values especially for heterogeneousformation rocks. This certainly may lead to different reservoir sizes along with thetechnical and economical consequences. The study presented in this article is meant to furtherinvestigate this question. The thrust of this study lies on the application of a newlyproposed method for determining porosity cut-off. It is put that with this new and reliablemethod – compared to the traditionally used method – a more conclusive answer can beachieved. For the purpose, a heterogeneous limestone reservoir in West Java – Indonesiais used. Evaluation, analysis, and application of the new method on data from the field’seight wells have shown that multiple porosity cut-off values are needed for better definitionsof reservoirs. Application of a single value for these reservoirs can still be regardedas unrepresentative. The fact underlines that – despite the new approach’s reliability –heterogeneity governs more over the use of either single or multiple cut-off values ratherthan limitations of method. The study also proves that the new method for determiningporosity cut-off works well for highly heterogeneous reservoir rocks.
A NEW APPROACH OF COMPOSITIONAL SIMULATION FOR A VOLATILE OIL RESERVOIR MODELING Ego Syahrial
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.33.1.658

Abstract

This paper proposes a new compositional simulation approach for a volatile oil reservoirmodelling. The proposed formulation has an implicit equation for the oil-phase pressureand water saturation, an explicit equation for the hydrocarbon saturation, and explicitequation for the overall composition of each hydrocarbon component that satisfiesthermodynamic equilibrium. An Equation of State for phase equilibrium and property calculationsis used in this new formulation. Interfacial tension effects are included in thisapproach to characterise the thermodynamically dynamic nature of the relative permeability.A two-dimensional relative permeability algorithm is included which handles lumpedhydrocarbon phase hydrocarbon phase as well as individual phase flows. For each gridblock two equations are required, namely total hydrocarbon and water-phase flow equations.These equations are highly non-linear and they are linearised by using Newton-Raphson method. The resulting equations are solved by an efficient Conjugate Gradientbased iterative technique to obtain pressures and saturations simultaneously, and hydrocarbon-phase saturations are deduced from their respective equations.The new compositional simulation approach is validated through analytical and numericalmethods. It is demonstrated in this present paper that the results are comparedfavourably with analytical techniques and published numerical results. They also confirmthat the proposed codified formulation is unconditionally stable and it is as stable as fullycompositional model yet the computational cost reduction was substantial.
RESERVOIR QUALITY REDUCTION CAUSED BY CLAY INDUCED DUCTILITY Junita Trivianty Musu; Bambang Widarsono
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.33.1.659

Abstract

Ductile components including rock fragments, clay, and matrix material are often consideredas the most important factors that control quality of shaly sandstones, which are usually characterized by low porosity and permeability. In presence of ductile components, the degree of quality reduction is affected mainly by distribution, occurences, and amounts of the ductile components. Therefore, the presence of ductile components affects rock petrophysics, and consequently has effect on fluid movements in reservoir during production. This paper presents results of the study on plug samples taken from five wells from various fields in Cooper Basin (Tirrawarra Sand), South Australia. The samples were studied petrographically using x-ray diffraction, optical petrography, and scanning electrone microscope. The results were integrated with routine and special core analysis data. The overall results show that the distribution and the amount of ductile components have significantly reduced porosity, hence the quality of the reservoir. However, the effect is different for different types of porosity, and this certainly is valuable addition to our understanding over permeability behavior of shaly sandstones.
Worksheet Screening Of Co2 Eor Sequestration Potential In Indonesia Usman Pasarai; Utomo Pratama I; Danang Sismartono
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.33.1.806

Abstract

CO2 injection into subsurface with the purpose to increase incremental oil production had been popularized in 1970s in US. Nowadays, this type of EOR methods not only offers more oil but also utilizing reservoir as CO2 storage in the context of CO2 emission abatement. The objective of this research is to produce simple and efficient worksheet on EXCEL base in order to asses and screen out quickly the potential of implementation of CO2 EOR sequestration in depleted oil fields in Indonesia.Key elements of this worksheet comprise engineering aspect and economical aspect. A sequence workflow of technical performance of CO2 flooding was done using streamline simulator in which outstanding output from simulator needs robust data preparation and cautious parameter set up. For the case studied here, total incremental oil recovery at the end of the project is 4.52% from original oil in place (IOIP) or about 6.23 MMSTB. “Prophet” was used to simulate CO2 sequestration during CO2 EOR incorporating residual trapping. The amount of CO2 trapped in reservoir was acquired by subtracting the total injected CO2 with CO2 produced. The total capital expenditure for sequestration CO2 EOR studied here is estimated $48.3 MM. It is expected that $16.5 MM will be placed in service by 1st year with the remaining $31.7 MM to be placed in service by 2nd year. Annual average operating cost was estimated to be $5.4 MM. As for fiscal terms, the following assumptions have been incorporated into the economic evaluations: (1) FTP 10%, (2) Investment Credit 17%, (3) Contractor Oil Split 26.6018%, (4) Government Split 73.3982%, and (5) Tax 44%. The economic analyses were carried out based on the project life time 7 years and the sales of incremental oil amount 5.6 MMSTB with an assumption that price for oil was $68 per barrel based on monthly average OPEC Basket Price during April-09 until March-10. Economic results of the development with discount factor 7 percent as indicated has a Contractor DCF Rate of Return 53.3 percent, Contractor Net Present Value $31.3 MM, and revenue to the Government of Indonesia $188.2 MM. With this economic indicator, the project of Sequestration CO2 EOR is economically feasible. The developed worksheet enables to do quick judgment on the viability a CO2 EOR sequestration project hence make it easier to someone who wants to screen out a large number of reservoirs rather than using detailed numerical simulator. It will much more saved time and decrease works intensity.
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.
Effect Of Composition Variation With Depth On Volatile Oil Reservoirs Ego Syahrial
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.33.1.809

Abstract

It has been known that the distribution of hydrocarbon components in a fluid column is affected of gravity. Many authors have shown the effect of composition variation within a hydrocarbon column due to gravity. In thick reservoirs as the depth increases, the mole fraction of the lighter hydrocarbon decreases, whereas the heavy fraction increases. These variations may affect reservoir fluid properties considerably. In studying reservoir processes, especially with miscible displacements, it is essential to have of underlying mechanisms. In this paper, we investigate the effect of composition variation with depth on volatile oil under depletion and miscible gas processes. A ternary diagram was used to identify the process displacement mechanisms at different locations. A new efficient compositional simulationapproach was used to model the volatile oil reservoir bahaviour. It was shown that the decreasing light component with depth caused different miscible displacement processes as the oil composition move toward limiting tie line in the ternary diagram. Saturation and reservoir pressures variation with depth were not linear in a thick reservoir. This non linearity increased with the increased in volatility of the oil. In the case of depletion, the concentration of light component decreased below its original composition in the produced layers. In vaporising-gas drive the light component gradually vaporized from the bottom to the top of reservoir, whereas the intermediate component decreased below its original composition from the bottom to the top of the reservoir
Palaeoenvironments Of The Permian-Cretaceous Sediments Of The Bintuni Bay, Papua Eko B Lelono; Mufdi Firdaus; Tri Bambang SR
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.33.1.810

Abstract

This paper presents a part of the result of Lemigas in-house research entitled Paleogeography and Hydrocarbon Potentiality of the pre-Tertiary Sediment of the Bintuni Basin, Papua, which is financially supported by the Government through a project so called DIPA 2009. In addition, this paper specifically discusses a palaeoenvironment of the Late Permian-Cretaceous sediment of the Bintuni Bay based on biostratigraphy. Data used in this paper is mostly secondary data obtained from National Data Center and an oil company which is therefore, classified as a confidential information. Paleoenvironment appeared in a non-marine setting during Permian-Triassic to form Ainim Formation in which, shale of this formation acts as a primary sourcerock for the studied area. Early Jurassic is characterised by a non-deposition, whilst Middle Jurassic is indicated by the occurrence of non-marine environment to deposit fluvial sandstone of the Lower Kembelangan Formation which is considered to be a main reservoir. Subsequently, environment shifted to the marine setting where deep marine shale occurred to form caprock. Mean while, the Early Cretaceous sediment disappears from the studied area suggesting massive erosion. Finally, depositional environment took place in the marine setting during the Late Cretaceous resulting in the formation of deep marine shale of Jass Formation which may contribute as a caprock in the element of petroleum system
Laboratory Study Of Calcium Sulfate Solubility Calculation By Using Skillman, Mcdonald, And Stiff Method Darwita Darwita
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.33.1.811

Abstract

Calcium sulfate scale is one of serious problems and must be solved accurately in petroleum industry. It can plug pore media consequently decreases production rate. Therefore, it is very important to know injection water quality of S1, S2, S3 water samples by means of calculating CaSO4 solubility. Each injection water sample has different CaSO4  solubility. The CaSO4 solubility of S3 produced water is usually higher than S2 and S1 solubility. Because it contains the highest calcium and sulfate ion concentrations compared with S2 and S1. No CaSO4 scale is found in all analyzed water sample.
THE INFLUENCE OF OLEFIN CONTENT IN GASOLINE AGAINST DEPOSIT BUILD UP ON INTAKE VALVE OF MOTOR BIKE ENGINE Nur Ahadiat; Djainuddin Semar
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.33.1.948

Abstract

The specification of gasoline 91, according to Dirjen Migas decree No. 3674 K/24/DJM/2006 dated March,17 2006 define the limit (maximum) of aromatic content 50%volume, and benzene 5.0% volume, but does not define boundary for olefin content as its is regulated in others countries. Olefin compound happened to be saturated hydrocarbon, its has higher octane number, unstable, produces gum that later on could build up as deposit on intake valve of combustion chamber or nozzle tip of fuel injection system. The objective of this study was to know how far the influence of olefin content in gasoline 91 to deposit build-up in intake valve of motor bike engine after cruising on road test for certain distance. For this purpose, the motor bike will be fueled with gasoline 91 with olefin content variations and will be compared to motor bike that cruised at the same route and distance accumulation with regular gasoline 91. Effect of several volume variety of olefin content in gasoline againts deposit development of intake valve engine will be discuss in this paper.

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