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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 24 Documents
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Search results for , issue "Vol 48 No 3 (2025)" : 24 Documents clear
One Phase Well Design for Minimum Drilling Cost at ZAZ Field Kharisma Idea; Yaumil Hasbiyallah; Kesuma Ardhana Oerika; Muhammad Yusrin
Scientific Contributions Oil and Gas Vol 48 No 3 (2025)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v48i3.1888

Abstract

Drilling cost components including rig, casing and accessories, well surface equipment, drilling mud, bits, cementing, and casing installation substantially influence the overall drilling cost. The One Phase Well (OPW) design is implemented by eliminating the surface casing, which is conventionally applied in casing designs for wells in the ZAZ Field. This study evaluates drilling parameters such as well data, well trajectory, pore pressure–fracture gradient, drilling time, material usage, and drilling costs. A well profile analysis is conducted to compare the Three Phase Well (TPW) and One Phase Well (OPW) designs. Analysis of drilling time, materials, and drilling costs is carried out to evaluate the cost reduction difference between the Three Phase Well (TPW) method and the One Phase Well (OPW) method.The OPW design reduces rig rental costs by 34.9%, bit costs by 53.9%, casing costs by 20.5%, wellhead costs by 8.7%, and mud costs by 3.7%. In contrast, cementing costs increase by 0.7%, and casing installation incurs an additional cost of USD 24,017. Overall, the total drilling cost difference between OPW and TPW amounts to USD 68,633, with OPW achieving a 12.7% reduction in overall drilling costs compared to TPW.
The Effect of TiO2 Nanoparticles on The Performance of Kappaphycus Alvarezii Biopolymer for Enhanced Oil Recovery Muhammad Taufiq Fathaddin; Onnie Ridaliani Prapansya; Pri Agung Rakhmanto; Dwi Atty Mardiana; Wydhea Ayu Septianingrum; Sonny Irawan; Ridho Abdillah
Scientific Contributions Oil and Gas Vol 48 No 3 (2025)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v48i3.1909

Abstract

This study investigates the performance of a novel, environmentally friendly nanocomposite, utilizing the natural biopolymer Kappaphycus alvarezii enhanced with TiO2 nanoparticles, for Enhanced Oil Recovery (EOR) via polymer flooding. The application of this nanocomposite was aimed to simultaneously enhance microscopic displacement and macroscopic sweep efficiency. The research method used was laboratory testing which included solution stability, viscosity, interfacial tension (IFT), and rock wettability tests in various polymer concentrations (2,000–6,000 ppm), TiO₂ (2,000–4,000 ppm), and salinity (6,000–30,000 ppm) at temperatures of 30–80°C. Quantitative laboratory results confirm fluid property improvements: TiO2 addition increased the solution viscosity by up to 11 cP where an average increase up to 7.11% in high-salinity brines, reduced the Interfacial Tension (IFT) from 7.54 dyne/cm to 6.80 dyne/cm (a 9.8% reduction), and decreased the contact angle from 39.05° to 28.51°, confirming enhanced water-wetness. Core flooding experiments demonstrated that the polymer flooding yielded an incremental oil recovery factor after waterflooding ranging from 6.67% to 27.67%. The maximum total oil recovery achieved was 69.17% at the optimal concentration of Polymer 4,000 ppm and TiO2 2,000 ppm. These specific findings highlight the significant potential of the Kappaphycus alvarezii–TiO2 nanocomposite as an effective EOR agent.
Influence of Installation Orientation and Cone Angle on Pressure Drop and Filtration Efficiency of Conical Strainers Amnur Akhyan; Mhd Dhowiy Hussein; Mohd Azahari Bin Razali
Scientific Contributions Oil and Gas Vol 48 No 3 (2025)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v48i3.1910

Abstract

Cone strainers are very important in oil and gas pipeline systems because they prevent particles from entering the system and damaging pumps, compressors, and other critical equipment. This study experimentally examines the effects of cone angle, installation orientation, and open area ratio (OAR) on pressure drop (ΔP) and filtration efficiency (η) in conical filters. Four setups were examined with cone angles of 74° and 81° and hole diameters of 4 mm and 6 mm, at flow rates between 15 to 30 m³/hour. The results reveal that the 81° configuration (OAR = 38%) with unidirectional installation has the lowest pressure drop (1,250–2,500 Pa) and a filtration efficiency of over 92%, making it ideal for energy-efficient use. Conversely, the 74° cone can capture more particles (>93%) but experiences higher pressure loss (up to 9,500 Pa), making it suitable for applications requiring very stringent filtering. Installing the counter-current way was shown to increase turbulence and lower efficiency by up to 20%, which demonstrates the importance of the correct installation orientation for maintaining hydrodynamic stability and filtering effectiveness. These results highlight the critical need to optimise cone geometry and OAR to strike a balance between energy efficiency, hydraulic stability, and filtering performance. For pre-filtration and equipment protection in oil and gas systems, the optimal setup is an 81° angle, a 6 mm hole, a 38% OAR, and unidirectional flow. This configuration can contribute to smoother operations, energy savings, and reduced maintenance requirements.
Reduction of Carbon Emission in East Java Power Generation Sector Through The Use of Saline Aquifer as CO2 Storage - A Conceptual Study Bambang Widarsono; Suliantara Suliantara; Herru L Setiawan; Mohamad Romli; Nurkamelia Nurkamelia; Sugihardjo Sugihardjo; Panca W. Sukarno; Junita T Musu; Tri Muji Susantoro; Herizal Herizal; Usman Pasarai; Aziz M Lubad; Sunting Kepies; Diana Dwiyanarti; Rudi S. Wijayako; Muhamad Budisatya; Devitra Saka Rani
Scientific Contributions Oil and Gas Vol 48 No 3 (2025)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v48i3.1926

Abstract

East Java region, as one of the most industrialized regions in Indonesia, is a significant contributor to national greenhouse gas (GHG) emissions, and therefore may play a significant role in supporting the national commitment to reach net zero emissions (NZE). This study is made to provide an example of how a conceptual CCS scheme using a saline aquifer is applied in the region. Tanjung Awar-awar coal-fired power plant, which is located in the Tuban city area on the northern coast of East Java, is selected as the GHG source. With its power generation capacity of 2 x 350 MW, it emits 4.5 Mt CO2e annually. The extensively distributed Kujung carbonate formation is chosen as the CO2 saline aquifer storage. Amidst the typical data rarity commonly faced in preliminary studies on saline aquifers, modeling for CO2 storage has been performed using all available primary and secondary data from all available sources. The most likely estimate of storage resource shows 479 Mt CO2e (status: 3U in SRMS classification system), with its A2 block possessing 162.78 MtCO2 storage resource. The CO2 injection scheme is essentially a volumetric balancing between CO2 emissions and injection rates through injection wells. Well injection capacities are estimated, and must be able to cope with CO2 emissions from the power plant. Accordingly, two CCS scenarios of 50% CO2 capture (Scenario A; 4,671 tons/day) and 100% CO2 capture (Scenario B; 9,342 tons/day) are set. To serve the two scenarios, four (4) and eight (8) horizontal wells are needed, respectively. A similar approach has also been made for vertical injection wells. Following the assumptions set in the CCS scheme, a total of 34,098,300 tons and 68,189,300 tons of CO2 can be stored in a 20-year injection permit for Scenario A and Scenario B, respectively. Nonetheless, these figures constitute just fairly small fractions of the Kujung A2 block’s storage resource. This shows the huge potential of the Kujung Formation to act as a saline aquifer storage for CCS schemes in the East Java region. This also presents the potential of the Kujung Formation to sustain multi-CO2 sources and prolonged injection schemes. Despite many challenges faced, especially in relation to data scarcity, the results may serve as a reference for more detailed project-based studies in the future.

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