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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 5 Documents
 1 
Search results for , issue "Vol 42 No 3 (2019)" : 5 Documents clear
PROGRESSING CAVITY PUMP AS A SOLUTION TO INCREASE PRODUCTIVITY OF HIGHLY VISCOUS OIL WELLS WITH SAND PRODUCTION: A CASE STUDY OF FIELD X Amanda Efa D; Ronaldo H.T.; Wijoyo N.D.; Steven Chandra; Prasandi AA
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.42.3.376

Abstract

Major oil fi elds in Indonesia have been experiencing massive decline in production, accompanied by excessive sand production that is not benefi cial to the integrity of the production system. Sand production has been known to increase the potential of corrosion, reducing lifetime of well equipment, and also known to shut in wells completely due to sand buildup in wellbore. Progressive Cavity Pump has been proposed as a solution to withstand these complications, due to its nature that can handle many types of fl uids and even produced solid. The idea is then tested to a mature Alabaster fi eld where the majority of the wells have been shut in due to excessive sand problem and low productivity. It is worth nothing that after installing the PCP, production modeling indicates possibility of sustaining production through the application of PCP, where the production increases around 120 STB/ day. Although PCP has proven its effectiveness, it is important to note that auxiliary sand mitigation techniques is required to maintain facilities integrity after several years of production.
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.
SHALE GAS SWEET SPOT POTENTIAL OF TUNGKAL GRABEN, JAMBI SUB-BASIN SOUTH SUMATERA BASIN Taufik Ramli; M. Heri Hermiyanto Z; Andy Setyo Wibowo
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.42.3.397

Abstract

The Tungkal Graben is located in Jambi Sub-basin, the northern part of South Sumatera Basin. This basin is known as one of the largest hydrocarbons producing basin in Indonesia. There are several proven source rocks in the South Sumatera Basin. The paralic shales and coal horizon of Talangakar Formation (TAF) are known as primary source rock in this basin and considered as a reservoir of shale gas-bearing in Tungkal Graben Area as well. This study used surface geological data that was collected from the southern foot of Tiga Puluh Mountain as the outcrop analogy and subsurface data (existing well and seismic data) in Tungkal Graben Area. This study applied integrated methods including environmental deposition analysis, organic geochemistry analysis, petrophysical analysis, seismic interpretation, sweet spot delineation, and volumetric of gas in place (GIP) calculation. TAF observed both on the outcrop and well is transition deposit that consists of the dominance of shale and siltstone with interbedded of coal, sandstone, and limestone. Shale and siltstone of TAF have characteristic which is appropriate as a shale gas bearing, with sufficient organic content richness, suitable kerogen type, its maturity entering the early gas generation and proper brittleness index (BI). The sweet spot area is an area that has met the criteria for potential shale gas and determined by pay zone criteria. Depend on the criteria, Net to gross for shale gas is 0.158, early gas generation estimated at a depth of 10250 feet, and sweet spot area reaches 8.9 x 108 ft2. Thus, the total potential of shale gas resources from the calculation using the Ambrose method is 2.12 TCF.
SUSTAINABLE DEVELOPMENT AREA OF ONSHORE LIQFEFIED NATFRAL GAS (OLNG) IN EAST INDONESIA Djoko Sunarjanto; Suliantara .; Nurus Firdaus; Heru L Setiawan; Rismoyo Bayu
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.42.3.398

Abstract

This study is supporting the safety downstream oil and gas industrial area from geological disasters, intended to bridge the needs of geological and geomorphological data in Onshore Refinery Natural Gas site selection. The methodology is comparison analysis and comparative studies to several refineries. Optimization of integrated potential regions is pursued in a sustainable manner, its Onshore Refinery Natural Gas activities with the others development sector. It is recommended the selection locations based on adjacent islands, integrate with several utilizing resources. Regional data such coastal areas with certain coastal heights, potential groundwater and runoff area, are relatively secured from geological disasters and integrated utilization of natural gas reserves for power plants, fertilizer plants, ammonia and so on. Eastern Indonesia has specific geological character in term of rock types and morphology that developed in this region. It is an important consideration in sustainable development area related to refinery development. The advantages of this study is optimization of coastal physiography for determining the selected parameters of Onshore Refinery Natural Gas location. The goal is to increase the local content related to geological engineering and geohazards activities in the sustainable development and selection of Onshore Refinery Natural Gas locations in Indonesia.
LATE CRETACEOFS SEDIMENTARY ROCK IN BARITO BASIN, INDONESIA: LITHOLOGY, PALEONTOLOGY, AND PALEOENVIRONMENT Akmaluddin Akmaluddin; Muhammad Virgiana A; Salahuddin Husein; Muhammad I. Novian; Nugroho I. Setiawan; Didit Hadi Barianto; Sunjaya E.S.; Banti T. Tampubolon
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.42.3.400

Abstract

The Barito Basin so far known as back-arc basin that formed by the rifting in Early Tertiary, which the oldest sedimentary rock in this basin is believed has a Middle Eocene to Early Oligocene age. However, this research will present new evidence regarding the existence of sedimentary rocks that are older than Cenozoic age in the Barito Basin. This research was carried out on Bongkang-2 well, as the main data, and other five wells which have an indication of the discovery of Pre-Tertiary sedimentary rocks, which are generally located in the northern part of the Barito Basin. Integration of mud log data, petrography, paleontology, and dip-meter data, resulting the identification of lithology, age and depositional environment, and then interpretation of the paleoenvironment of the Barito Basin in the Late Cretaceous is carried out. Based on the analysis of data, it is show that Pre-Tertiary sedimentary rocks found in the six wells analyzed has Cenomanian age, which is indicated by the presence of large foraminifera fossils in the form of Sulcoperculina sp. and Orbitolina sp. in Bongkang-2, Hayup-1 and Hayup-3 wells, as well as palynomorph fossils in the form of Cicatrico- sisporites dorogensis, A. tricornitatus, Aquilapollenites sp., Distaverrusporites margaritus and Classopolis cf. classoides in Bagok-1 and Bagok-2 wells. In addition, based on lithological analysis, in the Bongkang-2, Hayup-1 and Hayup-2 wells lithology develops in the form of limestone, shale and sandstone, while in the Didi-1, Bagok-1 and Bagok-2 wells lithology develops in the form of shale with sandstone and pyroclastic – volcaniclastics rock intercalation. Then, based on the integration of lithology and paleontology analysis, it is known that in the Cenomanian age, terrestrial environments developed in the western part of the Barito Basin, while in the eastern part the shallow marine environment developed.

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