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INDONESIA
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 5 Documents
 1 
Search results for , issue "Vol 37 No 2 (2014)" : 5 Documents clear
DISCREPANCY OF MCMP DERIVED FROM EXPERIMENTS AND PREDICTION MODELS OF SOME INDONESIAN OIL FIELDS Sugihardjo Sugihardjo
Scientific Contributions Oil and Gas Vol 37 No 2 (2014)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.37.2.627

Abstract

Most of oil fi elds in Indonesian have been categorized as mature fi elds, since the primary stages of theoil production nearly fi nished. Therefore EOR technology is the only option to rejuvenate those old oil fi eldsto increase the oil recovery. CO2 miscible fl ooding, one of the proven EOR technology, can be implementedin some Indonesia oil fi elds if they fulfi ll the screening criteria for CO2 injection. Laboratory works initiallyshould be carried out to determine some parameters for calibrating the reservoir simulation program. Themost important parameter is MCMP (multiple contact miscibility pressure), this pressure level can be usedto determine the displacement effi ciency of the CO2 injection. Above the MCMP will be more effi cientcompare to below MCMP injection pressure. MCMP is normally can be obtained in the lab by a Slim tubeapparatus. In case there are no oil and gas sample available, some correlations based on the empiricalfi eld data are also available in the literature as well as EOS (equation of state) for predicting MCMP. Somereservoir fl uids MCMP have been evaluated using those three methods. Then, discrepancies were calculatedto compare the results of Slim tube tests, correlations and EOS calculation. Four correlations such as NPC(National Petroleum Council), Cronquist et al, Yellig-Metcalfe, Holm-Yosendal and one EOS modeling ofPeng-Robinson (1978) have been proposed to predict the MCMP fourteen reservoirs. Moreover, those MCMPwere also run using Slim tube. Holm-Yosendal correlation has nine reservoirs and secondly Yellig-Metcalfemethod possesses six reservoirs with discrepancy below 10% compare to MCMP obtained from Slim Tubetests. While the other methods are not appropriate as well as Peng-Robinson EOS modeling without anylaboratory data for calibration.
COMPARATIVE STUDY OF POROSITY DETERMINATION METHODS FOR OGIP IN FRACTURED BASEMENT RESERVOIR Usman Pasarai Pasarai
Scientific Contributions Oil and Gas Vol 37 No 2 (2014)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.37.2.628

Abstract

Determination of porosity in fractured basement reservoirs has always been a challenge due to thecomplexity of processes involved in the generating of pore structure as well as the rock heterogeneity. As aresult, estimate of original gas in place (OGIP) is subject to substantial uncertainty. Intention of this studyis to evaluate the most effective method to determine fracture porosity and hence reducing uncertainty ofOGIP volume in the fractured basement reservoir. The evaluation is based on comparison to the core derivedporosity as the point of reference. Included in this evaluation are the techniques of secondary porosity index(SPI), dipole share imager (DSI), dual laterolog (DL), and formation micro imager (FMI). The SPI andDSI logs derived fracture porosities are found over optimistic to the core reference. The FMI determinedfracture porosities are considered in fair agreement with core data. Results from the DL technique comparevery favorably with core data and thought to be the best calculation of porosity in the fractured basementgas reservoir investigated in this study. Those results supported by data that have been collected from thepublished literatures. Found that typical value of fracture porosities in the fractured basement rocks isless than 1%. The comparative study presented here helps in reducing uncertainty related to the fracturedbasement reservoir development.
POROSITY VERSUS DEPTH CHARACTERISTICS OF SOME RESERVOIR SANDSTONES IN WESTERN INDONESIA Bambang Widarsono
Scientific Contributions Oil and Gas Vol 37 No 2 (2014)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.37.2.629

Abstract

Porosity is a petrophysical property that always draws attention due to its central role in determiningstorage capacity of hydrocarbon reservoirs. Accuracy for predicting porosity in reservoir affects much ofmany petroleum production related activities. Accordingly, various attempts have been devoted to study andmodel rock porosity including its relation with depth. In this study porosity data from as many as 4654 coresamples (1773 full-diameter core plugs and 2881 sidewall core samples) is used. The core samples were takenfrom 549 wells in 222 fi elds/structures located in eight producing sedimentary basins in western Indonesia.Main results of the study are facts that existing porosity-depth models derived from data obtained from otherregions are not usable for Indonesian cases, and therefore porosity-depth models are established for theeight sedimentary basins. It is hoped that these models can contribute signifi cantly to the understanding ofrock porosity trends with depth in western Indonesia.
PALEOGENE PALYNOLOGY OF THE CENTRAL SUMATERA BASIN Eko Budi Lelono; Christina Ani Setyaningsih; L Nugrahaningsih
Scientific Contributions Oil and Gas Vol 37 No 2 (2014)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.37.2.632

Abstract

Unlike rich pollen assemblage of other Paleogene sediments in western Indonesia (as seen in NanggulanFormation of Central Java, Tanjung Formation of South Kalimantan and Malawa Formation of SouthSulawesi), pollen assemblage of Paleogene sediments in the Central Sumatera Basin is considerablylow. Referring to the occurrence of Oligocene spore Cicatricosisporites dorogensis supported by pollenPalmaepollenites kutchensis and Meyeripollis naharkotensis, it is inferred that the studied sediment isassigned to Oligocene age. This is strengthened by the disappearance of many key Indian affi nities whicharrived in the Sundaland during Eocene. Palynologically, this study separates the Brown Shale from theUpper Red Bed. The Brown Shale is dominated by fresh water pollen without brackish element suggestingnon-marine environment. This sequence might have been formed in syn-rift setting. Surprisingly, lacustrineindicators of fresh water algae Botriococcus and Pediastrum (as found in the lacustrine sediment of TalangAkar Formation of Sunda-Asri Basin) are absent. Mean while, the Upper Red Bed is marked by signifi cantoccurrence of brackish palynomorphs suggesting the infl uence of marine environment during post-rift period.This condition proves the existence of the transgressive phase where sedimentation started in freshwaterenvironment during the Brown Shale deposition which gradually shifted into transition (shallow marine)environment during the Upper Red Bed sedimentation.
DEVELOPMENT OF ULTRASONOGRAPHY FOR DOWNHOLE WELL INSPECTION Gathuk Widiyanto
Scientific Contributions Oil and Gas Vol 37 No 2 (2014)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.37.2.633

Abstract

One technique to increase oil production rate in marginal and suspended wells is solving mechanicalproblem. Success parameter to solve the mechanical problem is to identify this problem properly andaccurately. One of the tools to identify the well integrity including mechanical problem in oil and gasindustry is downhole camera used to describe bore hole conditions. Image is very important and is usedas main parameter to determine the production and operation strategy. So, imaging technology transfer isvery important especially on proven technology. Ultrasonography is proven technology in medical disciplineto create image within human body without signifi cant error. This research tries to apply ultrasonographytechnology in oil and gas industry. Recently, design and prototype of downhole inspection tools stage III havebeen completed. Prototype consists of electronic system, mechanical system and information system includedacquisition system. Laboratory test of these tools has been conducted successfully. Acquisition system usesmemory system within dry battery to avoid operation problem at fi eld test. Several advantages of this toolsare the small number data as per user’s required, user friendly and simple in operation.

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