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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 619 Documents
 8   9   10   11   12 
THE INFLUENCE OF MOLYBDENUM DISULPHIDE-FRICTION MODIFIER (FM) ADDITIVE INCREMENT ON THE FRICTION AND WEAR PREVENTION BEHAVIOUR OF HVI 60 BASE OIL Muhammad Hanifuddin; Nofrijon Sofyan
Scientific Contributions Oil and Gas Vol 38 No 2 (2015)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.38.2.542

Abstract

Friction will always be found in a mechanical system. It is therefore necessary to minimize friction, so it becomes a more effi cient use of energy. This paper discusses the infl uence of MoS2 friction modifier (FM) additive in the form of powder with two different mesh sizes, i.e. 90 nm and 1.5 um, on the friction and wear characteristic of HVI 60 base oil. The variation of MoS2 were 0,05%; 0,1%; 0,5% weight whereas MoS2 1.5 um were 0,05%; 0,1%; 0,5%; 1% and 2% weight. MoS2 additive 90 nm was mixed with base oil and stirred with magnetic stirrer for 60 minutes at 50oC and homogenized in an ultrasonic homogenizer for 1 hour. For the MoS2 1.5 um, the additive was mixed with base oil and stirred with magnetic stirrer for 60 minutes at 75oC without using an ultrasonic homogenizer. Friction and wear characteristics of these mixtures were tested using four-ball and SRV test-rig. The wear scars were analyzed by using a scanning electron microscope (SEM). The results of the tests showed that the addition of 0.1% weight MoS2 additive, both in 90 nm and 1.5 um, resulted in an optimum increase in friction and wear characteristic of 23% and 11%, respectively. Observation on the wear scar showed that adhesive and abrasive wear mechanisms were involved in the wear process. The results of this research could be applied in the production of lubricating oils that can improve engine performance. Keywords: additive, friction, wear, molybdenum disulfi de, four-ball
PEPTIDE SURFACTANT FOR EOR APPLICATION Usman Usman
Scientific Contributions Oil and Gas Vol 38 No 2 (2015)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.38.2.543

Abstract

Motivated by recent advances on the peptides surfactants that capable of forming emulsion stabilization by lowering the interfacial tension, an extensive set of tests were carried out to further investigate the applicability of peptide molecules for enhanced oil recovery application. A designed peptide surfactant using protein biotechnology approach was laboratory tested at three samples representing the different oil characteristics, water formation, and reservoir rock. The best performance of peptide surfactant obtained is of sample A. Peptide surfactant is able to form microemulsion Type III at pH 11. It can lower the interfacial tension value until the range of 10-2 dyne/cm at 25°C, even though itsn’t reached the desired target yet which is 10-3 dyne/cm or even less. It can also change rock wettability from water wet into strong water wet. Sample A has relatively short hydrocarbon chain compared to samples B and C, it is classifi ed as intermediate oil, medium salinity for water formation, and rock mineral is dominated with quartz without gypsum that is very harmful to the fuction of surfactant. The developed peptide surfactant hasn’t been stable at high temperature yet. When tested at 70°C, the interfacial tension value increase to around 10-1 dyne/cm. Displacement effi ciency using oil sample A is less than 1%. Based on these results, the next peptide surfactant design will be focused on resistance capability improvement to temperature and peptide amino acid structure position to produce the better result of surfactant. The performance test results of peptide surfactant presented in this paper is valuable in designing specifi c peptide surfactant for certain oil fi eld.
HYDRATE MITIGATION FOR DEEP WATER AND LONG DISTANCE PIPELINE – FLOW ASSURANCE APPROACH Riesto Mundi Karono
Scientific Contributions Oil and Gas Vol 38 No 2 (2015)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.38.2.544

Abstract

The existence of gas hydrates is well known in the oil and gas production industry. The components are dominated by methane and naturally occur in deep marine sediment along continental margins. Although hydrates may be of potential benefi t both as a hydrocarbon resource and as a mean of storing and transmitting natural gas, traditionally their presence is considered to be an operational and a safety problem. They can form at the pressures and temperatures found in natural gas and oil pipelines causing blockages, especially when temperature falls signifi cantly, such as when closing in a well or fl owing gas through a choke. This could deliver a serious potential problem for oil and gas offshore production either for its equipment or personnel. Besides the variation of gas rate to avoid hydrates forming, currently there are two methods that have been used widely to prevent hydrates formation in production pipelines - thermal insulation and chemical inhibitor. Each method has its own benefits. PIPESIM software application can be used to evaluate both mitigation methods and to then fi nd which is the best scenario based on lowest cost, shortest period of application and less adversity.
A CASE STUDY OF FORMATION DAMAGE MITIGATION ON “X” FIELD, SUMATRA Septi Anggraeni
Scientific Contributions Oil and Gas Vol 38 No 3 (2015)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.38.3.546

Abstract

Formation damage might cause low oil well productivity, therefore it is very important to effectively handle this issue. In fact, every operation in the field-drilling, completion, workover, production and stimulation, is a potential source of formation damage. In this case study, the oil company “A” plan to dispose produced water into Formation B, J, K, D,M. Laboratory tests were performed to investigate the effect of the injection of water into the reservoir formation. The experiment was conducted by measuring water permeability as a function of fluid volume injection. In addition, XRD analysis was also performed on effluent filtrate to support the results. Prior to investigating the sensitivity of reservoir rock to the fluid injection, the samples were injected with fresh water, saline water, produced water collected from Central Injection Facility, and also Filtered CIF Water. The results indicated that all formations were sensitive to fresh water and produced water. Moreover, the use of a filter will improve the water quality. Therefore, the produced water should be treated by using a filter and increasing water salinity. The XRD analysis showed that the potential damage is mostly caused by fine migration clay, however, swelling clay is also present in the small part of formation. The test results will be used for water treatment design, so as to minimize formation damage.
OPTIMIZATION OF MEASUREMENT SPEED FOR SPECTRAL GAMMA RAY AND CLAY MINERAL IDENTIFICATION Irawan Y. Tribuana; Ade Yogi; Prabowo Prabowo; Andy S. Wibowo; Puteri Sudija; Yudhi Durahman
Scientific Contributions Oil and Gas Vol 38 No 3 (2015)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.38.3.547

Abstract

Gamma ray log is a logging tool to capture the radioactive level of a rock or formation measured in API units. This logging tool generally has a capability to differentiate between permeable and impermeable layers. Usually the impermeable layer tends to have higher radioactivity compared to the permeable one except for the feldspar bearing formation. In addition, another capability of this logging tool is to determine the kind of clay mineral, by using ratio data between Thorium and Potassium. This laboratory experiment used Spectral Gamma Ray (SGR) equipment at LEMIGAS Routine Core Laboratory. The quality of gamma ray log measurement is significantly affected by the speed of the conveyor belt. During the experiment, the measurement speed of 30 m/hour is the optimum speed to achieve good quality data and time efficiency with the data amount of 169 points/meter. The result of SGR measurement gives the reading on the content of Uranium, Thorium and Potassium. The Thorium and Potassium content are compared and plotted in Quirein graphic which was modified by Schlumberger in 1985. Using this crossplot, we can identify the presence of Chlorite, Montmorillonite, Kaolinite, Illite, mixed layer Feldspar, Mica, and Glauconite minerals. A case study conducted on Wells A1, A2, A3 and A4, indicated that the result of this crossplot were similar to the measurement using XRD.
HYDROCARBON SHALE POTENTIAL IN TALANG AKAR AND LAHAT FORMATIONS ON SOUTH AND CENTRAL PALEMBANG SUB BASIN Julikah Julikah; Sriwidjaya Sriwidjaya; Jonathan Setyoko Hadimuljono; Panuju Panuju
Scientific Contributions Oil and Gas Vol 38 No 3 (2015)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.38.3.549

Abstract

South and Central Palembang Sub - basin over Talang Akar (TAF) and the Lemat/Lahat Formations (LEF/LAF) has shale hydrocarbons (HC shale) which are considerably promising. Seismic interpretation results shows potential HC shale scattered in several areas around the Rukam-1, Kemang-1, Lion-1 and Tepus-1 wells. Generally, thermal modeling results indicates early maturity of oil on the value of Ro = 0.6% at about 2000 m depth (h), the formation of oil on the value Ro = (0.7-0.9)% at between (2200 £ h <3100) m depth and formation of gas at Ro values between (0.9-1.2)% at a depth between (3100-3500)m. Talang Akar and Lahat/Lemat Formations have a shallow marine depositional environment with Type II/III kerogen and lacustrine with Type III kerogen. Based on advanced seismic data processing (a method of seismic attributes and spectral decomposition) these areas are expected to have a TOC>2% value that qualifies as shale HC. The assessment (P-50) of potential non-conventional oil and gas resources at Talang Akar and Lahat/Lemat Formations is estimated to be fairly large (up to 4200 MMBOE).
THE INFLUENCE OF MEDIA COMPOSITION TO THE GROWTH OF SCENEDESMUS SP. MICROALGAE IN VARIED MEDIA Mochammad Fierdaus; Onie Kristiawan
Scientific Contributions Oil and Gas Vol 38 No 3 (2015)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.38.3.550

Abstract

Media culture is one of the important factors in the growth of microalgae. Culture medium contains macro and micro nutrition required for the growth of microalgae. Composition of nutrition and nutrition concentrations determine the production of microalgae biomass and nutrient content. The aim of this study is to evaluate the effect of medium composition variation to Scenedesmus sp growth in laboratory-scale in order to get the optimized composition of media for microalgae Scenedesmus sp. This study was conducted in a laboratory scale. The growth medium that were used in this study were: BBL sm, SS, MN, M4N, “Sederhana 2”, and “Sederhana 3” medium. The microalgae that were used in this study were mixed culture Chlorophyceae microalgae which is dominated by Scenedesmus sp. The parameters observed were pH, optical density (OD), cell density and temperature. The results show that of the 6 variations of the growth medium used in this study M4N medium is the best medium for the growth of microalgae. At the end of the operation, cell density of Scenedesmus sp. from M4N medium was 306.83 x 106 cell/mL with a dark green color for the culture. The coefficient growth of Scenedesmus sp. which is grown in M4N medium was 0,36. This is likely to be due to the composition of nutrients in the medium M4N which were more complete than other media.
Bojongmanik Formation Sedimentation Mechanism in the Middle to Late Miocene (N9-N17) in the Rangkasbitung Basin Tety Syahrulyati; Vijaya Isnaniawardhani; Mega Fattima Rosana; Winantris Winantris
Scientific Contributions Oil and Gas Vol 43 No 3 (2020)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.43.3.551

Abstract

The Rangkasbitung Basin, is a part of Banten Depression which was formed by a normal fault, and then fi lled by marine deposits. This research carried out to understand the sedimentation process of Middle Miocene Bojongmanik deposits, the age, paleoenvironment and lithology (sediment sequence). In this research, 55 samples were taken from the study area, approximately 595 km2. Measurement of the stratigraphic section is carried out to determine the correlation both vertically and horizontally. The residue of dissolving peroxide method was carried out during the samples preparation. Then genus and species of planktonic and benthonic foraminifera were identifi ed and determined. The foraminifera analysis guide has been used to determine the age and depositional environment. The sequences of Bojongmanik Formation were deposited in Middle to Upper Miocene (N9 to N17). Based on the planktonic foraminifera distribution, the succession of each sequence can be correlated. During Middle Miocene (N9 - N12), the lowest part of Bojongmanik Formation is deposited at 100m-200m and 100m-80m depth, while in the other site, the correlated sequence is recorded that deposited at 80m-20m depth (outer to edge of inner neritic facies). In late Middle Miocene (N13 - N14), the regression process was happened. Almost the succession was deposited on land, while in deep site, a less part of sediments was formed as land facies but the most of it deposited as marine facies. In Upper Miocene (N 15 - N 17), the sedimentation continued in the transitional to edge neritic in back mangrove to mangrove environmental setting (upper to lower delta plain), and in other sites the sediment is no longer formed. Based on distribution of benthonic foraminifera there are observed the biofacies changes laterally. In bathymetric of depositional environment maps it can be depicted two higher paleoenvironmental sites (Cigudeg and Muncang highs) and two lower sites (Leuwiliang and Jasinga basins).
Reducing Residual Moveout Seismic Anisotropy Model Using Three-Ray GMA (General Moveout Approximation) Egie Wijaksono; Humbang Purba
Scientific Contributions Oil and Gas Vol 43 No 3 (2020)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.43.3.553

Abstract

A “ hockey stick” phenomenon is one of anisotropic effects that should be eliminated in marine seismic data. It can increase residual moveout at the far offsets and impact to the distortion of refl ection event amplitude, eventually, reduce the seismic imaging quality. Conventional hyperbolic moveout approximation, an algorithm isotropic model commonly used for seismic processing, has a drawback in supressing such phenomenon. It is also not reliable for medium anisotropy model and long offset data. Many researchers formulated nonhyperbolic moveout approimations but it has limitation analysis for inteval offset-depth ratio (ODR) more than four. We present three-ray generalized moveout approximation (three-ray GMA) for transversely isotropic medium with vertical axis of symmetry (VTI), which is a modifi ed non-hyperbolic moveout approximation from original GMA, to cover up of the weakness of the hyperbolic approximation. The objective of this study is to eliminate “ hockey stick” effect and minimize the residual moveout much smaller at once at the far offsets (offsetdepth ratio > 4). In this study, we used synthetic data for single layer model in VTI medium to calculate relative traveltime error for each recent method over a range of offsets (0 ≤ ODR ≤ 6) and anisotropic parameters (0 ≤  ≤ 0.5). We also make comparative method for multi layer and implement it in a velocity analysis and residual moveout calculation. The three-ray GMA shows a better capability than comparative method to reduce residual moveout for larger offset. This result is important for enhancing seismic imaging.
Source Sink Matching for Field Scale CCUS CO2-EOR Application in Indonesia Usman Usman; Dadan DSM Saputra; Nurus Firdaus
Scientific Contributions Oil and Gas Vol 44 No 2 (2021)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.44.2.586

Abstract

The carbon capture utilization and storage (CCUS) referred in this paper is limited to the use of CO2 to the enhanced oil recovery (CO2-EOR). The CCUS CO2-EOR technology can magnify oil production substantially while a consistent amount of the CO2 injected remains sequestrated in the reservoir, which is beneficial for reducing the greenhouse gas emission. Therefore, this technology is a potentially attractive win-win solution for Indonesia to meet the goal of improved energy supply and security, while also reducing CO2 emissions over the long term. The success of CCUS depends on the proper sources-sinks matching. This paper presents a systematic approach to pairing the CO2 captured from industrial activities with suitable oil fields for CO2-EOR. Inventories of CO2 sources and oil reservoirs were done through survey and data questionnaires. The process of sources-sinks matching was preceded by identifying the CO2 sources within the radius of 100 and 200 km from each oil field and clustering the fields within the same radius from each CO2 source. Each cluster is mapped on the GIS platform included existing and planning right of way for trunk pipelines. Pairing of source-sink are ranked to identify high priority development. Results of this study should be interest to project developers, policymakers, government agencies, academicians, civil society and environmental non-governmental organization in order to enable them to assess the role of CCUS CO2-EOR as a major carbon management strategy.

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