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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 6 Documents
 1 
Search results for , issue "Vol 34 No 2 (2011)" : 6 Documents clear
Rock Wettability Characteristics Of Some Indonesian Limestones Case Study: Baturaja Formation Bambang Widarsono
Scientific Contributions Oil and Gas Vol 34 No 2 (2011)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.34.2.796

Abstract

Rock wettability plays a very important role in affecting various rock physical properties such as relative permeability and capillary pressure. Common practice at present is that carbonate rocks are assumed to be preferentially oil wet in nature. This assumption may prove fatal since the need of true knowledge over the real wettability for one’s carbonate reservoir is often neglected, and wettability aspect in reservoir modeling is in turn based on assumption. To prove over reliability of the assumption a study is carried out using information from 350 core samples taken from Baturaja Formation. The choice for the Baturaja limestone is basically based on the fact that it is a mature productive rock formation and its extensive spread into three of the most productive sedimentary basin in Indonesia, Northwest Java Basin, South Sumatra Basin, and Sunda Basin. The study proves that the assumption of the generally oil wet limestone does not apply for Baturaja limestone. The Baturaja limestone tend to exhibit, quantitatively, equality in their tendency towards oil wettability and water wettability and leave some proportion to neutral or mix wettability as well. However, when a more detailed comparison is made results show that qualitatively the limestone are indeed more inclined to oil wettability than water wettability even though this finding is insufficient to support a conclusion that the Baturaja limestone are specifically oil wet. Other finding from comparison with past studies also shows that limestone may behave in the way sandstones do. Both limestone and sandstones may vary in the same way and no assumption over their preferential wettability is justified without direct measurements. Wettability alteration as the result of hot core cleaning following the widely accepted standard procedure is also strongly indicated. It is therefore concluded that the practice has to be abandoned for a better and reliable laboratory testing results.
Oligocene Palynological Zonation Scheme From East Java Sea Eko Budi Lelono; Robert J Morley
Scientific Contributions Oil and Gas Vol 34 No 2 (2011)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.34.2.797

Abstract

Systematic biostratigraphic analyses have been undertaken on the Oligocene clastic and carbonate Kujung Formation from the East Java Sea, North of Madura. The succession has been examined mainly using cutting samples in two wells, using a combination of foraminiferal, nannofossil and palynological analyses at regular spacing. Nannofossil analysis indicates that the Late Oligocene to basal Early Miocene succession is more or less complete, with zones NP24, NP25 and NN1 are all being well developed. In addition, the Early Oligocene is indentified by larger foraminifera indicating the Tc/ Td Letter Stage. Because the traditional palynological zonation of Morley (1978) does not work well in this area, the succession has been divided into broad assemblage zones, which appear to be controlled mainly by climate. These zones are OL-1, OL-2, OL-3, OL-4 and OL-5. Zone OL-1 is based essentially on the absence of seasonal climate and riparian elements, whilst zone OL-2 is characterized by the regular occurrence of seasonal climate elements, especially of Malvacipollis diversus. Zone OL-3 is indicated by common to abundant Dacrydium and Casuarina pollen, with a strong acme of dinoflagellate cysts dominated by Operculodinium spp. and Spiniferites spp., whereas zone OL-4 is marked by abundant Dacrydium and regular Casuarina pollen, but low representation of riparian elements. Finally, the youngest zone is OL-5 which is characterized by reduced Dacrydium and Casuarina pollen, and increased riparian elements. The above palynological zonation suggests climate change, which closely parallels the climate succession from West Java Sea (but with changes less pronounced). Therefore, this study provides a well dated Oligocene palynological zonation which can be applied across Java.
Risks Analysis Of Carbon Dioxide Storage In Geological Formations Lusyana Lusyana; M Dwi Atmanto
Scientific Contributions Oil and Gas Vol 34 No 2 (2011)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.34.2.798

Abstract

Concerning to global climate change, Indonesia has committed to reduce CO2 emissions. The CO2 injection and storage in underground geologic formations is one practical method for reducing large volumes of CO2 emissions into the atmosphere. However, the risks associated with the geological storage of CO2 are a key factor affecting the implementation of Carbon Capture and Storage (CCS). A better understanding and quantification of these risks is required to ensure risks associated with CO2 storage in underground formations meets acceptable safety standards. In this paper, the risks are quantified and justified by using Subjective Risk Assessment method. The results show that the risks are low through medium for three types of geological formations i.e. depleted oil and gas reservoirs, unmineable coal seams, and deep saline reservoirs.
Polymer Properties Determination For Designing Chemical Flooding Sugihardjo Sugihardjo
Scientific Contributions Oil and Gas Vol 34 No 2 (2011)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.34.2.799

Abstract

Waterflooding became the standard practice in many reservoirs formation in petroleum industries, the strengths and weaknesses of the methods were quite well established. In particular, the inefficiency of the waterflood oil displacement mechanism as a result of either an unfavorable mobility ratio or heterogeneity was largely identified. Therefore, chemicals injections as the improvement displacement processes had been proposed to support petroleum industries to recover the production of oil. Chemical injection normally consists of alkaline, surfactant, and polymer (ASP). They could be injected as standalone fluid or mixture of fluids; it depends upon the injection fluid design appropriate for particular field. Polymer solution could be prepared for mixtures of injection fluid and or as chase fluid injection which is injected behind surfactant or ASP. The main function of polymer solution primarily is to viscosity the injection water as a mobility control. This work is proposed to determine the important polymer properties which are suitable for mobility control in such EOR plan in the particular field. This field is sandstone reservoir with oil gravity of 23 to 26oAPI and viscosity of 3cp at 90oC. Two kinds of polymers have been chosen such as: HPAM-1 and HPAM-2 and subject to be tested for the properties characteristic. Intensive works have been done to evaluate the bulk polymer properties at laboratory scale which include rheology, filtration, thermal stability, retention/adsorption, and injectivity or permeability reduction tests. The results indicated that HPAM-1 polymer is suitable for injection fluid design for Zone-B while HPAM-2 for Zone-A.
The Importance Of Litho-Facies Distinction In Determining The Most Representative Cementation Factors For Well-Log Evaluation : An Old Issue Persistently Neglected Bambang Widarsono
Scientific Contributions Oil and Gas Vol 34 No 2 (2011)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.34.2.800

Abstract

Cementation factor is a parameter always required in any conventional open-hole log analysis leading to determination of water saturation. Considering the central of water saturation in the estimation of hydrocarbon in place and reserves, any error in the use of the parameter may prove fatal. A common practice in the oil industry is that acquisition of laboratory-derived cementation factor has never been given a proper attention. It occurs very often that too few samples – hardly represent the rocks of reservoir of concern – are assigned for laboratory test. The practical use of the parameter in the log analysis also often draw question, in which un-representative cementation factor is arbitrarily used due to lack of the data. The effect of this practice has long been known but is often neglected – with all of its consequences – up to present day. This study tries to revive the awareness through presenting a fact that cementation factor may vary due to differences in litho-facies characteristics. Formation resistivity factor data from forty-seven limestone coreplug samples were taken from a West Java (WJ) field. Visual description over the samples has shown that they belong to several litho-facies types. Results of the study have mainly proved that different litho-facies type may have significantly different cementation factors. An averaging effect is also obvious when data from all samples are processed collectively. The effect of improper use of cementation factor is shown through the application of three water saturation models through which erroneous water saturation estimates are produced. The finding of the study is again hoped to reinforce the awareness of the use of proper and representative cementation factor
Ranking Of Indonesia Sedimentary Basin And Storage Capacity Estimates For Co2 Geological Storage Utomo P Iskandar; Sudarman Sofyan; Usman Usman
Scientific Contributions Oil and Gas Vol 34 No 2 (2011)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.34.2.801

Abstract

The various possible strategies to combat global warming are explored within a wideranging of efforts. Practical solutions will need to stop or even reverse the build-up of CO2 in the environment by using existing technology that has not been integrated, carbon dioxide capture and storage (CCS) (Hansson, 2008). The main objectives of this study are to develop criteria for sedimentary basins ranking system in terms of their suitability for CO2 storage and estimate the storage capacity available. We adapt the method developed by Bachu (2003) to the Indonesia geological characteristics. Once the criteria has been developed and the basins ranked based on their suitability, oil and gas fields located within these basins were estimated their potential storage capacity using the methodology developed by Carbon Sequestration Leadership Forum (CSLF). From 60 identified sedimentary basins, Kutei, Tarakan and South Sumatera basins are respectively positioned in top three of the ranking system. Well known geological structure, adequate data, relatively stable geological structure and established infrastructures are the main factors make these basins have higher suitability. Estimation result showed from 48 fields that are considered depleted from their Np/Ult ratio (hydrocarbon cumulative production over ultimate recovery), Riau and South Sumatera region have large storage capacities which are around 229 and 144 MtCO2 respectively. The ranking of Indonesia sedimentary basins can then be used in making decisions for the large-scale implementation of CCS Project. The potential storage capacity might increase as data more available. The estimates resulted from this study is not a conclusive estimation where degree of geological and economic uncertainty associated with a capacity estimate is still high. However, from this estimation shows that Indonesia has huge potential of CO2 storage in depleted oil and gas reservoirs

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