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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
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PORE PRESSURE ESTIMATION IN HARD UNLOADING-OVERPRESSURE ZONE USING SINGLE COMPACTION EQUATION, CASE STUDY: LOWER KUTAI BASIN Irawan Y Tribuana; Usep Mulyadi; Agus M Ramdhan; Asep H Rustam
Scientific Contributions Oil and Gas Vol 39 No 2 (2016)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.39.2.105

Abstract

Pore pressure estimation in hard-overpressure zone is very important in drilling activities. Correct and precise estimation are able to reduce the cost for drilling due to reduced non-productive time (NPT) and in increase in safety aspect while drilling. Pore pressure estimation is done by post-mortem analysis in exploration wells using validation points from pressure measurement data such as Drill Stem Testing (DST), Modular Dynamic Tester (MDT), and Repeat Formation Tester (RFT). A wireline logs data used for identification of the type of overpressure and predicts pore pressure magnitude in the shale section. Through the correlation between effective-stress and velocity, a single compaction equation was obtained for the Lower Kutai Basin with the value of : 5.097 * σ 0.854. By using this single equation, pre-drill pore pressure prediction activity will be more easy and could estimate pore pressure in hard-overpressure zone precisesly.
TRIBOLOGICAL PROPERTIES OF MINERAL BASE OILS WITH TUNGSTEN DISULPHIDE
(WS2) NANOPARTICLES IN BOUNDARY LUBRICATION CONDITIONS Setyo Widodo; M Hanifuddin; Rona Malam Karina
Scientific Contributions Oil and Gas Vol 39 No 2 (2016)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.39.2.106

Abstract

Friction affects the efficiency of a mechanical system. This paper discusses the influence of Tungsten Disulphide (WS2) as a friction modifier (FM). Friction and wear characteristics of base oil as a result of the addition of 0.1% and 0.5 % weight of WS2 were studied. WS2 nanoparticles were mixed with base oil using magnetic stirrer at 50oC for 60 minutes, then were homogenized in an ultrasonic homogenizer for 1 hour. Friction and wear characteristic of these mixtures were tested using four-ball and HFRR test-rig. The results show that the addition of both 0.1% and 0.5% WS2 nanoparticles increased by around 40% the anti-wear characteristic of mineral base oil group I and 12% for other groups of base oils. The increase in friction coefficients was in a range of 7.5% to 35% as a result of the addition of additives.
IN SILICO POTENTIAL ANALYSIS OF X6D MODEL OF PEPTIDE SURFACTANT FOR ENHANCED OIL RECOVERY Cut Nanda Sari; Usman Usman; Rukman Hertadi; Tegar Nurwahyu Wijaya; Leni Herlina; Ken Sawitri Suliandari; Syafrizal Syafrizal; Onie Kristiawan
Scientific Contributions Oil and Gas Vol 39 No 2 (2016)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.39.2.107

Abstract

Peptides and their derivatives can be applied in enhanced oil recovery (EOR) due to their ability to form an emulsion with hydrophobic molecules. However, peptide research for EOR application, either theoretical or computational studies, is still limited. The purpose of this research is to analyse the potency of the X6D model of surfactant peptide for EOR by molecular dynamics simulations in oil-water interface. Molecular dynamics simulation using GROMACS Software with Martini force field can assess a peptide’s ability for self-assembly and emulsification on a microscopic scale. Molecular dynamics simulations combined with coarse grained models will give information about the dynamics of peptide molecules in oil-water interface and the calculation of interfacial tension value. Four designs of X6D model: F6D, L6D, V6D, and I6D are simulated on the oil-water interface. The value of interfacial tension from simulation show the trend of F6D L6D > I6D > V6D. The results indicate that V6D has the greatest reduction in interfacial tension and has the stability until 90°C with the salinity of at least 1M NaCl.
RAY-BINNING ANGLE STACK DOMAIN IN ENHANCING THE ROBUSTNESS OF CONVERTED-WAVE SEISMIC JOINT INVERSION Wahyu Triyoso; Madaniya Oktariena; Lucky Kriski Muhtar
Scientific Contributions Oil and Gas Vol 41 No 3 (2018)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.41.3.330

Abstract

Converted-Wave Seismic has been proven as imaging alternative in aiding conventional seismic data when passing through gas cloud accumulation. However, asymmetrical approximation effect during Converted-Wave Seismic binning still remains in offset domain. PS-Reflection events in offset-domain are mapped using common-ray re-sorting technique by implementing the basic Snell’s Law of Mode Conversion. This produces an Angle Profile correspondent with the PP incident angle. Re-sorting the angle of converted-wave ray path to the PP-Wave propagation within the common imaging point, the Converted-Wave seismic would share similar angle range. Thus, improving the match in PP to PS event as data input preparation for Joint Inversion. Grouping the angle based on AVA Analysis, followed by stacking the Angle Profile into Common-Ray Partial Angle Stack, had proven to eliminate the fault shadow sagging zone and gas absorption illumination area in Converted-Wave Seismic. The final result of PP-Seismic imaging is more coherent with the Converted-Wave Seismic, in term of event alignment and amplitude character. This result lead to more robust PP-PS Joint Inversion, as the coherency between input data is an important key in simultaneous process. The comparison on derived Vp/Vs shows better improvements of subsurface imaging, especially in the near-surface gas masking area of conventional seismic.
MOLECULAR DYNAMICS STUDY OF OLEIC ACID-BASED SURFACTANTS FOR ENHANCED OIL RECOVERY Aang Suhendar; Rukman Hertadi; Yani F Alli
Scientific Contributions Oil and Gas Vol 41 No 3 (2018)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.41.3.331

Abstract

Surfactants have been intensively used for Enhanced Oil Recovery (EOR). Nevertheless, environmental issues cause some surfactants to become unfavored in EOR application. Biodegradable surfactants are the suitable choice to make the environment safer. However, screening surfactants that have a good performance for EOR are time-consuming and costly. Molecular Dynamics (MD) simulation is an alternative solution to reduce cost and time. In the present study, oleic acid-based surfactants that combined with the various length of polyethylene glycol were studied. The potential surfactants were screened by MD simulation to evaluate their ability to reduce the Interfacial Tension (IFT) between oil and water layers, which is the by GROMACS software with Gromos force field and SPC water model. Carboxyl-terminal of the oleic acid was substituted by a different length of polyethylene glycol. All MD simulations were prepared in octadecane–water mixture with temperature ranges of 303-363 K. Our simulations found that the increasing number of polyethylene glycol was not always followed by the decreasing of IFT value between octadecane and water layers. These results were validated with the experimental data and found the similar IFT profile. The simulation of oil emulsification showed that all surfactant samples have good performance and stability as exhibited by their emulsification rate and emulsion stability in different temperatures. The last test to get the best surfactant was the wetability test. The simulation gave the result that both PEG100-oleic and PEG400-oleic were able to change wetability of rocks from oil-wet to water-wet. Accordingly, PEG400-oleic is the best nonionic surfactant candidate due to its performance in each simulation test.
FOAMING CAN REDUCE LUBRICATION OF LUBRICANTS SO CAUSING WEAR Rona Malam Karina; M Hanifuddin; Setyo Wibowo
Scientific Contributions Oil and Gas Vol 41 No 3 (2018)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.41.3.332

Abstract

Foaming on oil has a very undesirable effect which can cause an increase in oxidation by intensive mixture with air, damage to cavitation, and insufficient oil transportation in the lubrication circulation system which can cause poor lubrication. Adding the appropriate antifoam additives is one way to avoidfoaming. To determine the tendency of foaming formation which has an impact on the stability of the performance of lubricating oil, so that there is wear and tear in research in the laboratory by means of; 6 types of lubricating oil taken from the market are tested for viscosity, index viscosity, flash point, pour point and color. As well as to determine the effect of foam formation tested foaming tendency / stability and wear before and after antifoam added from 6 (six) types of lubricated oil obtained from the market. The result after adding antifoam additives, three types (GB, SH, and MH) of six types of lubricated oil were tested, the tendency of foaming and the wear results met the required limits, namely 0/50/0 ml for foaming tendency and maximum 0.5 mm for wear, while for 3 (three) oils, the results are not satisfying the required limits.
KINETICS OF BATCH MICROBIAL DEGRADATION OF PHENOL BY PSEUDOMONAS AERUGINOSA AND DEEP-SEA SEDIMENT BACTERIA: SCALE-UP Syafrizal Syafrizal
Scientific Contributions Oil and Gas Vol 41 No 3 (2018)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.41.3.333

Abstract

Petroleum that is produced from several oil wells produces a fluid containing a mixture of petroleum, natural gas and produced water. The produced water usually contains hazardous chemicals such as hydrocarbons, sulfides, ammonia, phenols and other heavy metals. One of the high pollutants in the water produced is phenol. Through a biodegradation process, the contents of phenolic compounds in the produced water are expected to be reduced so that it meets the quality standards of waste water for oil and gas exploration and production activities. This research is development of the results of previous studies using a bioreactor with a larger scale, namely 3 L. The degradation process of phenolic compounds is carried out in optimal conditions, namely: pH 7, temperature 300C, and selected simple media: NP (5: 1) derived from urea and NPK + 0.1% yeast extract. The results of this study indicated that P. aeruginos and bacterial consortium may degrade phenolic compounds very well, which was 5.3 times faster than the previous studies. The biodegradation percentage was 98.40% in P. aeruginosa and 99.03% in bacterial  consortium respectively. The monod kinetics model approach was successfully carried out and gave the value of parameters μMax, Km, YS/X, and μd respectively of 0.6305 hours-1, 0.0280 mg/L, 7 × 10-7 mg/L/ CFU/mL, and 0.00575 hours-1 in P. aeruginosa and 0.3272 hours-1, 0.0355 mg/L, 6.63 × 10-7 mg/L/CFU/ mL, and 0.00279 hours-1 in bacterial consortium. Based on the valuesof these parameters, P. aeruginosa has better affinity and growth.
PARABOLIC TROUGH COLLECTOR CONCENTRATING SOLAR POWER AS STEAM PRODUCER USING SOLAR IRRADIATION OF CEPU, BLORA, CENTRAL JAVA Andrian Aziz Burhan A.S; Dzul Fadhli Aziz; Muhammad Nur Hidayat
Scientific Contributions Oil and Gas Vol 41 No 3 (2018)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.41.3.334

Abstract

Alternative energy sources has grown lately, especially for solar energy harnessed with Concentrating Solar Power (CSP) to produce steam that will be converted into a certain form of energy. The steam produced can also be used for petroleum industry to reduce the fuel usage in boilers. Daily solar irradiation of 5.18001 – 5.21909 kWh/m2 received by Cepu, Blora, Central Java, is deemed sufficient for CSP with parabolic trough collector (PTC) as steam producer. This paper describes the designing of the parabolic trough collector CSP, temperature increase gained from PTC, and peak temperature gained from 1 PTC. The initial experiment of PTC in cloudy, sunny, and cloudy-sunny-cloudy weather resulting in water temperature increase gained to be 172oC, 401.1oC, 285.9oC using Cepu District solar irradiation. Further experiments will be done to find out the relationship between temperature over time.
MULTI-POLARIZATION FOR ANALYSIS OF GEOLOGICAL STRUCTURES AS FORMATION OF HYDROCARBON TRAPS CONTROLLER IN EAST JAVA BASIN Indah Crystiana; Hartono Hartono; Retnadi Heru Jatmiko; Taufan Junaedi
Scientific Contributions Oil and Gas Vol 41 No 2 (2018)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.41.2.335

Abstract

The decline in oil reserves and the increasing demand for oil and gas energy led to the search for new reserves. The geological structure pattern used to know the pattern of distribution and formation of hydrocarbons traps in the East Java Basin is one of the important information that can be extracted through remote sensing data of multi-polarization system. The multi-polarization system of this study merged the \ Alos Palsar imagery with HH and HV polarization, and Sentinel Image polarized VV and VH. Processing both image data through calibration, multilook, speckle fi ltering, geometric correction and mosaic. Filtered imagery is composite and sharpening. The fi ltering technique use Lee 5x5 kernel fi lter and then continue with 5x5 median fi lter. The results of multi-polarization system image interpretation can be identifi ed by fold, thrust faults, normal faults, strike-slip faults, bedding, and closure structure. In the formation research area the structure lasted two periods, with the main emphasis N-S in the order of 1 and the main direction of the SW-NE direction in the order-2. The hydrocarbon traps and exploration targets can be distinguished in three zones (Zone A, Zone B, and Zone C). Closure in Zone A includes closures 3, 4, 5, 7, 8, 9, 10, 11, 22, 23, 24, 25, 26, 27, 28, 29, 30. Closure in Zone B includes closures 1, 2, 6, 12, 13, 14, 15, 16, 17, 31, 32. Closure on Zone C includes closure18, 19, 20, 21.
WELL AND OUTCROP CORRELATION IN THE EASTERN PART OF AKIMEUGAH BASIN, PAPUA: MESOZOIC PLAY POTENTIAL Rakhmat Fakhruddin; Taufi k Ramli; Hanif Mersil Saleh
Scientific Contributions Oil and Gas Vol 41 No 2 (2018)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.41.2.336

Abstract

Mesozoic sediments are the main objective for hydrocarbon exploration in the eastern part of Akimeugah Basin, Papua. However, little information is currently available on paleogeography and subsurface distribution of the Mesozoic rock unit. This study analyzed Mesozoic rock unit from outcrops at Wamena and surrounding area to wells data in the eastern part of Akimeugah Basin, Papua. Outcrop and well correlation was made to interpret paleogeography of Mesozoic unit. This study was using existin 2D seismic and passive seismic tomography data to determine the distribution of Mesozoic rock unit in the subsurface and its hydrocarbon potential. The Mesozoic rock unit in the eastern part of Akimeugah Basin is divided into four formations based on their lithological characteristic. Respectively from old to young, Kopai, Woniwogi, Piniya and Ekmai Formation. The depositional environment of Mesozoic rock unit in the southern part of the study area is shore/tidal to shelf and basin fl oor in the northern part. Three Mesozoic potential plays in the studied area are divided into 1) Central Range Mountains thrust-fold belt play, 2) Akimeugah low land thrust-fold belt play and 3) Tanah Merah pinch-out play. The results presented in this paper are expected to be a guide for further hydrocarbon exploration in the study area. Mesozoic sediments are the main objective for hydrocarbon exploration in the eastern part of Akimeugah Basin, Papua. However, little information is currently available on paleogeography and subsurface distribution of the Mesozoic rock unit. This study analyzed Mesozoic rock unit from outcropsat Wamena and surrounding area to wells data in the eastern part of Akimeugah Basin, Papua. Outcrop and well correlation was made to interpret paleogeography of Mesozoic unit. This study was using existing 2D seismic and passive seismic tomography data to determine the distribution of Mesozoic rock unit in the subsurface and its hydrocarbon potential. The Mesozoic rock unit in the eastern part of Akimeugah Basin is divided into four formations based on their lithological characteristic. Respectively from old to young, Kopai, Woniwogi, Piniya and Ekmai Formation. The depositional environment of Mesozoic rock unit in the southern part of the study area is shore/tidal to shelf and basin fl oor in the northern part. Three Mesozoic potential plays in the studied area are divided into 1) Central Range Mountains thrust-fold belt

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