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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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CATALYTIC PERFORMANCE OF ZSM-5 ZEOLITE IN HEAVY HYDROCARBON CATALYTIC CRACKING: A REVIEW Ratu Ulfiati
Scientific Contributions Oil and Gas Vol 42 No 1 (2019)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.42.1.384

Abstract

Low quality heavy oils and residues, which are subsequently obtained by processing heavy crudes, are considered as alternate suitable source for transportation fuels, energy and petrochemicals. ZSM-5 zeolite with high Si/Al ratio and modified with phosphorous and La has showed not only high selectivity to light olefins but also high hydrothermal stability for the steam catalytic cracking of naphtha. Kaolin is promising natural resource as raw material to synthesis of ZSM-5 zeolite. The utilization of acid catalysts with large pore size or hierarchically structured and high hydrothermal stability to resist the severity of the steam catalytic cracking (or thermal and catalytic cracking) operation conditions to maximize the olefin production.
THE EFFECT OF ELECTROLYTES ON POLYMER VISCOSITY FOR EFFECTIVENESS OF POLYMER INJECTION Yani Faozani Alli
Scientific Contributions Oil and Gas Vol 42 No 2 (2019)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.42.2.386

Abstract

The use of polymer for tertiary oil recovery has been known to be important as viscosity modifier to increase sweep efficiency of water flood and chemical flood. The most common polymer used for chemical flood is hydrolyzed polyacrylamide (HPAM) that owing large number of charges along the polymer chains. However, formation water as dissolution water contain high electrolytes that has a great effect on polymer viscosity, as well as responsible to generate the efficiency of polymer flooding. In this study, the effect of electrolytes from saline and cation divalent to the viscosity of polymer was investigated. Three studied polymers were dissolved in various concentration of saline and cation divalent by analyzing the compatibility, viscosity, and the filtration ratio of polymers. The results showed that the presence of electrolytes in every concentration of water did not impact the compatibility and filtration ratio of polymers. Whereas, the addition of sodium chloride as saline ionic and calcium chloride as cationic divalent were both reducing the viscosity of polymers. The lower viscosity of polymer related to the ability of polymer to expand the hydrodynamic which limited by the neutralization of internal repulsion of the electrolytes.
THE PREFERENTIAL WELD CORROSION OF X65 CARBON STEEL PIPELINE UNDER CO2 ENVIRONMENT Nofrizal Nofrizal; Susan A Impey; Konstantinos Georgarakis
Scientific Contributions Oil and Gas Vol 42 No 1 (2019)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.42.1.387

Abstract

Preferential weld corrosion (PWC) is a severe corrosion form of attack found in pipeline weldments in oil and gas industries. PWC occurs when the corrosion rate of the weld metal (WM) and heat affected zone (HAZ) is higher than the parent metal (PM). PWC was generated by galvanic corrosion mechanism due to dissimilarities in the composition and microstructure of the metal in the three weld regions.The aim of this research is to study the effect of flow rate on preferential weld corrosion (PWC) in X65 high strength pipeline steel using submerged jet impingement by investigating the mechanism of PWC on a weldment in artificial seawater saturated with carbon dioxide at 1 bar. A novel submerged jet impingement apparatus that consist of 3 rings (outer, inner and centre) was designed so that the parent material, heat affected zone and weld metal could be analysed in a high shear stress environment. Corrosion experiments were performed with X65 pipeline steel under no flow and flowing condition at 10 m/s at 30oC and pH4. The galvanic current characteristic between the weldment regions was recorded using a zero-resistance ammeter, and the self-corrosion was analysed by using linear polarisation resistance measurements. Total corrosion rates were calculated from the sum of the galvanic and self-corrosion contributions. The morphology, structure, chemical on the surface of X65 after corrosion process was investigated by means of scanning electron microscopy (SEM) and focus ion beam (FIB) to examine the corrosion product that form in brine containing dissolved carbon dioxide.In a no-flow condition, the result shows that the galvanic characteristics on all weldments were similar and the WM is cathodic and protected in comparison with the HAZ and PM. In flowing condition, the estimated flow rates associated with the different positions on the target vary depending on either (a) PM and HAZ or (b) the WM. The effects of target flow rate on WM have a similar trend, but the overall corrosion rates are greater due to PWC. The result of surface analysis after corrosion process showing that removal of hardened layer and subsurface cracking were causes of enhanced degradation.
STUDY ON CO2 SOAKING TIME AND “HUFF AND PUFF” INJECTION CYCLE EFFECT IN TIGHT PERMEABILITY RESERVOIR Muslim Abdurrahman; Fiki H. Ferizal; Dadan D.S.M. Saputra; Riri P. Sari
Scientific Contributions Oil and Gas Vol 42 No 1 (2019)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.42.1.388

Abstract

Oil and gas industry is struggling to improve oil production using several methods. CO2 injection is one of the advance proven technology to enhance oil production in numerous oil field in the world.  Key parameters during CO2 injection are viscosity reduction and oil swelling which can improve oil production. CO2 injection also has high possibility to be applied in Indonesia's oil fields due to abundant CO2 sources surrounding oil fields. R field is one of reservoir candidates that appropriate for CO2 injection. It has a low pressure and low oil recovery due to low permeability (1-26,2 mD).The CO2 injection technique used in this study was huff and puff that consist of injection, shut in, and production phases. The simulation was conducted using compositional simulator. There were two parameters chosen to be analyzed, which were soaking time and injection cycle. The objective of this study is to know the CO2 huff and puff perfomance for improving oil recovery on low permeability reservoir. The result of the soaking time cases yields optimum condition in 21 days. For the case of injection cycle, the result for optimum condition is in 2 injection cycles. The recovery factor (RF) for both optimum condition reaches 22.96% from the baseline without gas injection (RF 5.82%). 
The Effect of Carbon Steel Pipeline Deterioration to Water Injection Quality and Pressure Drop in Tanjung Waterflood Injection Plant. Migel Aldila; Iwan Febrianto; Akhmad Sudirman Saputra; Purnama Timur M.S; Ninik Purwatiningsih
Scientific Contributions Oil and Gas Vol 43 No 1 (2020)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.43.1.389

Abstract

In Tanjung, South Kalimantan, PT Pertamina EP (PEP) use secondary recovery (waterflood injection) for its technique for oil lifting. Low permeability reservoir condition make quality of water injection must be comply with low permeability reservoir requirement and the pressure injection must be around 1400 psig. In the common PEP injection plant, carbon steel pipeline is still used. Flakes accumulation and trapped oil could occur along with the deterioration of carbon steel pipeline. This matter can make the quality of requirements of injection water become worst. There were four data were analyzed; Oil content, TSS (Total Suspended Solid), Turbidity and Total Iron. The sample was taken at discharge pump and one of the injections well during 6 months.  Averagely the result of value of total iron, turbidity and oil content in injection well are bigger than discharge pump while TSS has little fluctuation. In conclusion, deterioration carbon steel pipeline has effect to reduce quality water injection become worst and effect of roughness of pipeline due to carbon steel deterioration can make the pressure drop is higher in accordance with the length.
Evaluation of Chemical for Sand Consolidation in Laboratory Scale Sugihardjo Sugihardjo
Scientific Contributions Oil and Gas Vol 43 No 1 (2020)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.43.1.391

Abstract

These paper contains a highlight of laboratory experiment to evaluate the work of chemical for sand consolidation to strengthen the bonding between grains of rock while do not cause permeability reduction significantly. This experiment used reservoir rock and fluids to understand the interaction between the chemical solution and the reservoir rock and fluid. Firstly, the reservoir rock and fluid were analyzed their properties. The rock has been analyzed using CT Scan to drill the best representative core plug for the experiments, using SEM to identify the pore throat and pore geometry of the rock, using XRD to determine the minerals composition which mostly quartz. While the fluids have been analyzed for the anions and cations content, viscosity and other important properties. The brine particle content and also particle size distribution of the rock have been also over lied in the graph in order to know the possibility of bridging particle in the pore throat, but the graph looks good that no problem may arise from the bridging particle. Chemical for Sand Consolidation has been used in this experiment. Sand consolidation chemical normally contain plastic resin that has a property of bonding between solid materials. It sticks on the surface of solid materials and bonding together.The core flooding experiments have been run for 4 times, 2 times using synthetic cores and the other two using native cores. The experiments used synthetic cores reduce the permeability significantly. However, after cutting both ends of the core the permeability has indicated improvement. The other 2 experiments using native cores have reduced the permeability approximately 4 times down. The last two experiments have no cutting the ends of core for further experiments, so they cannot be compared to the first two experiment. So, the experiment procedures must be improved for the next evaluation, such as during curing time the rate of injected oil may be increased to reduce the adsorption of chemical to the surface area of the pore and also to hinder the flocculation of chemical in the pore space.
Reserves and Resources Application in Welcoming Industry 4.0 Challenge Reza Alfajri; Hanief Jauhari; Andar Parulian Hutasoit; Sakti Parsaulian Siregar; Ernita Sembiring Meliala
Scientific Contributions Oil and Gas Vol 43 No 1 (2020)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.43.1.392

Abstract

In the era of industry 4.0, digitalization is a very significant step to adopt in a company. Every worldly renowned industry, oil and gas included, needs to assimilate this term into its business process. Reserves and resources report depicts an oil and gas company future cash flow, wealth, performance, as well as growth. Therefore, creating and managing this report need meticulous attention. In order to comply with demand in industry 4.0 and simplify reserves and resources reporting process, reserves and resources database and web-based application need to be developed. First task to carry in establishing database is to create and input master data. Companies’ asset is classified into four common entities: asset, area, structure, and layer – as the smallest entity. Layer contains fluid type and oil and gas specific attributes. After master data is established, a web-based application to handle data transaction and reporting is developed. In order to maintain data security, access to this application is restricted into four roles: data entry user, data approval user, administrator, and management. Every role has its own privilege, for example data entry user can create, edit, and view data, while management can only view it. Other employees that need to access this application are based on management approval and restricted into view privilege under their asset location. This application has already been tested in two reserves and resources reporting window, and underwent bug-fixing and improvement process. Implementing this application in oil and gas company’s business process gives several benefits: minimizing human error, establishing a single data source, and cutting time consumption in creating reserves and resources report. This application is the solution in creating and managing the report, as well as displaying data in graphical view to help management makes corporate decision.
Thru Tubing Fracturing Experience in Tight Sand Reservoir, Offshore North West Java. Adrianus Pradipta; Alvin Derry Wirawan; Janico Saverson Mulia; Muhammad Iqbal Prima
Scientific Contributions Oil and Gas Vol 43 No 1 (2020)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.43.1.393

Abstract

Lately, hydraulic Fracturing become common stimulation to improve economic by increase production and adding reserve through unconventional play from tight sand reservoir. The fracturing treatment creates highly conductive pathway to enhance production and well drainage which lead to add reserves. Mostly, Hydraulic Fracturing treatment had been performing in new development wells of infill wells. After successful resulted hydraulic fracturing campaign in new infill wells, there was a trial to perform hydraulic fracturing in existing well thru existing tubing completion. First well which was selected as first to perform remedial frac, thru tubing hydraulic fracturing is consider as a cheaper way to perform rigless hydraulic fracturing compare to hydraulic fracturing with rig. The main challenges during operational come from limitation of existing completion, several adjustment in design and operational should be perform to optimization during fracturing job. This paper presents the experience including fracturing limitation and fracturing design during performing first thru tubing hydraulic fracturing in tight sand reservoir in Offshore North West Java.
IMBIBITION WATER-OIL RELATIVE PERMEABILITY: INTRODUCTION OF WETTABILITY STRENGTH FOR ENHANCING MODEL ROBUSTNESS Bambang Widarsono
Scientific Contributions Oil and Gas Vol 42 No 1 (2019)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.42.1.395

Abstract

Water-oil relative permeabilty information of hydrocarbon reservoir rocks plays important roles in various modeling activities related to reservoir modeling and production forecast. The imbibition relative permeability scheme - the process of concern in this study affects many dynamic processes in reservoir. Water flooding and water encroachment form aquifer to oil zone in the reservoir are two two examples which representation in reservoir model requires the data. This study uses the standard Corey relative permeability model as a tool to study and model imbibition relative permeability behaviour of some reservoir rocks in Indonesia. Laboratory data from as many as 340 rock samples - sandstones and limestones - of various permeability and wettability from various oil fi elds in Indonesia is used. Activities in the modeling has pointed out the need to introduce two new empirical factors that relate to rock wettability and non- wetting fl ow hindrance to the model. The two factors appear to have signifi cantly improved the ability of the model to agree and match to the measured data. The modeling also produces suggested values of the factors for rock groups based on rock wettability type and strength, as well as on permeability categories. Comparison between modeling results before and after modifi cation has shown signifi cant improvement in validity of output.
INTEGRATED INITIAL WATER SATURATION MODELLING Falza Izza Wihdany; Dedy Irawan; Muhammad Rakha Utomo; Agung Mubaroqan Fitro
Scientific Contributions Oil and Gas Vol 42 No 3 (2019)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.42.3.396

Abstract

This study presents a new approach to estimate initial water saturation. The initial water saturation is determined by integrating formation tester (RFT), drill stem test (DST), well logging, and laboratory measurement (RCAL & SCAL) data. This method utilizes Brook-Correy’s parametrical equation to determine synthetic capillary pressure and initial water saturation as a function of depth and rock type. Rock type and permeability are distributed vertically by using well log interpretation. DST and formation tester data are used to control the initial water saturation calculation. The calculation needs to iterate Brook-Correy’s constant by using solver until the results are matching with all data. The precise step of this method is presented by using synthetic data (ideal reservoir characteristic). Case studies are provided for testing the proposed method. The product of this study is essential where well log data could be changed by time (production activity) and core measurement data are very limited. The results of case studies demonstrate that the method is not affected by rock mineralogy or reservoir condition. This new approach is successfully integrated and matched with field and laboratory measurement data. Moreover, the method could be applied in any reservoir.

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