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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 635 Documents
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An Integrated Analysis of Shut-In Well Reactivation for Oil Production Optimization in The DLN-11 Well Kristanto, Dedy; Yusgiantoro, Luky Agung; Hariyadi; Paradhita, Windyanesha
Scientific Contributions Oil and Gas Vol 49 No 1 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i1.2012

Abstract

DLN-11 well was temporarily shut-in due to excessive water production, which became the main issue causing a decline in daily oil production. Therefore, this study conducted an integrated analysis to determine the cause of excessive water production, so that appropriate mitigation measures could be implemented, as well as to formulate a well reactivation strategy aimed at optimizing oil production. The methodology in this study was carried out in an integrated manner through technical and economic evaluations. The technical analysis began with the application of the Chan diagnostic plot as an initial mitigation step, followed by the evaluation of data logging, core analysis data, and production data as advanced mitigation steps to obtain appropriate solutions for addressing production-related issues. In addition, an economic analysis was conducted as a basis for decision-making within a risk management framework. Based on the results of the integrated analysis between the Chan diagnostic plot method and cement evaluation data from Cement Bond Log (CBL), Variable Density Log (VDL) dan Ultra Sonic Imaging Tool (USIT), the high water cut in DLN-11 well, as a reactivation candidate, was caused by water channeling due to the presence of free pipe conditions, where the cement did not properly isolate the annulus between the casing and the formation. To overcome this issue, remedial cementing was carried out to improve the quality of cement bonding. Furthermore, based on the evaluation results of the C/O Log, DLN-11 well still owns five potential oil-bearing zones that can be produced. The reactivation strategy was implemented by opening the interval of 7927-7942 ftMD, resulting in a production rate of 549 BOPD with a water cut of 82%. The economic analysis results indicate that DLN-11 well yields an NPV of 1,256,000 US$, an IRR of 247.5%, and a Pay Out Time (POT) of 3 months and 16 days. Therefore, from both technical and economic perspectives, the implemented reactivation strategy for DLN-11 well has proven to increase oil production and generate positive economic indicators.
Analysis of The Effectiveness of KCL Polymer on Reactive Clay Formation in The 26 Section of A Field X Wastu, Apriandi Rizkina Rangga; Husla, Ridha; Ridaliani, Onnie; Suci, Farah Adiana Eka; Soekardy, Mentari Gracia; Azizah, Siti
Scientific Contributions Oil and Gas Vol 49 No 1 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i1.2015

Abstract

In geothermal well drilling, a primary challenge is clay swelling, particularly in reactive clay formations, where drilling success is largely determined by the type of drilling fluid used. Although gel polymer mud is commonly preferred, adding KCl polymer is often necessary to mitigate swelling in such formations. The study aims to evaluate the effectiveness of KCl polymer mud in mitigating clay reactivity in the 26-inch borehole section of X well in a geothermal field. The methodology began with the methylene blue test to assess clay reactivity, followed by the formulation of gel polymer and various concentrations of KCl polymer muds. A linear swell meter test was subsequently conducted to compare the swelling reduction performance of each mud type. The methylene blue test results indicated a smectite content of 60 meq/100 g, confirming the presence of reactive clay in the 26-inch borehole. LSM test results showed that the Gel Polymer mud exhibited 25.78% swelling over 11 hours, indicating it was ineffective for such formations. In contrast, the 7% KCl Polymer mud significantly reduced swelling to 16.38% over 8 hours. This improvement is attributed to the substitution of Na⁺ ions with K⁺ ions, which neutralizes negative charges on clay surfaces and reduces the clay's water-holding capacity. The findings confirm that KCl Polymer mud is more effective in minimizing clay swelling in reactive geothermal formations.
Techno-Economic Design of Onshore Gas Pipelines with High CO₂ and H₂S Content Pamungkas, Joko; Pramadewi , Indrianti; Hermawan, Yulius Deddy; Yuliestyan, Avido; Yusuf, Yusmardhany; Kurniawan, Aditya; Ramadhan, Muhammad Redo; Anggorowati, Heni; Perwitasari; Wulandari, Mutiara; Lazuardi, Muhammad Daffa
Scientific Contributions Oil and Gas Vol 49 No 1 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i1.2023

Abstract

This study develops a simulation-based techno-economic framework for designing an onshore gas trunkline system to accommodate production from newly developed wells in the X and Y Fields. The system transports 35 MMSCFD of untreated natural gas containing approximately 60 mol% CO₂ and 70 ppm H₂S, where high acid gas content and declining wellhead pressure impose constraints on pressure delivery, flow velocity, material selection, and lifecycle cost. Steady-state hydraulic simulations were performed using UniSim R490 to evaluate early- and mid-life production scenarios based on pressure drop and erosional velocity ratio (EVR) in accordance with API RP 14E. Comparative analysis of candidate pipeline diameters shows that a 12-inch trunkline maintains a minimum delivery pressure of 50 psig while keeping EVR below unity, thereby satisfying hydraulic and mechanical integrity requirements without excessive recompression. The integration of an onshore booster compressor mitigates reservoir pressure decline and sustains gas transport to the central processing facility. Material selection analysis identifies duplex stainless steel and SS 316 as technically viable options for CO₂-H₂S service under controlled operating conditions. Techno-economic evaluation indicates that the selected configuration minimizes total lifecycle cost relative to alternative designs, with estimated CAPEX of USD 228.43 million and annual OPEX of USD 142.19 million. The results demonstrate that integrated hydraulic optimization, sour-service material selection, and economic assessment provide a robust and economically optimized design approach for onshore sour gas pipeline systems.
A Decision-Oriented Techno-Economic Framework for Designing Fiscal Incentives in Horizontal Well Development of Marginal Oil Fields Achmad, Sudono; Prasetyo, Aries; Ramadhani, Najeela Faza
Scientific Contributions Oil and Gas Vol 49 No 1 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i1.2025

Abstract

Horizontal wells are widely recognized for improving reservoir contact and recovery; however, their application in marginal oil fields remains economically challenging due to high capital intensity and fiscal exposure. This study develops a decision-oriented techno-economic framework to evaluate the feasibility of horizontal well development under Indonesia’s Production Sharing Contract (PSC) regimes, namely PSC Cost Recovery and PSC Gross Split. Using a representative Indonesian marginal oil field, production forecasting, cost modeling, and cash-flow simulations are performed to assess project viability under Pessimistic, Moderate, and Optimistic Scenarios. Economic indicators, including Internal Rate of Return (IRR), Net Present Value (NPV), Payout Time (POT), and Government Take, are evaluated, followed by sensitivity and optimization analyses. The analysis confirms that PSC Cost Recovery consistently yields superior economic performance compared to PSC Gross Split, particularly for capital-intensive developments. Optimization results indicate that Contractor Split adjustment and CAPEX Efficiency are the most influential fiscal levers, while Investment Credit and First Tranche Petroleum (FTP) adjustments have a limited impact. This study identifies the quantitative incentive thresholds required to achieve a contractor Minimum Attractive Rate of Return (MARR) of 15%, offering practical guidance for policymakers and operators in structuring fiscal incentives for marginal field development. The findings provide a structured basis for aligning horizontal well deployment with fiscal policy to sustain upstream investment.
Effect of LHP Nanosilica on Sandstone Wettability and Oil Recovery by Imbibition in Crude Oils with Different API Jumiati, Wiwiek; Hani, Berkah; Yanti, Widia; Sutresno, Wahyu; Wihdany, Falza Izza; Ghaziyah, Hawa Syuraih; Herlambang, Karyanto; Celli, Agli Tori; Wibowo, Gilang Saputra
Scientific Contributions Oil and Gas Vol 49 No 1 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i1.2053

Abstract

This study investigates the influence of lipophobic–hydrophilic polysilicon (LHP) nanosilica on wettability alteration and oil recovery performance through spontaneous imbibition in initially neutral-wet sandstone. The novelty of this study lies in its systematic comparative framework using two crude oils with distinct API gravities and SARA compositions to evaluate the role of fluid–rock interactions in depth. Two crude oils with different API gravities were selected to evaluate the role of oil composition in fluid–rock interactions. Crude oil properties were characterized using SARA analysis, while imbibition tests were conducted using 5000 ppm brine and nanosilica dispersions at controlled concentrations. Wettability Index (WI) was determined using the Amott cell method, and Oil Recovery Factor (ORF) was calculated from produced oil volume. Results indicate that LHP nanosilica consistently shifts rock wettability toward more water-wet conditions. The lighter crude oil exhibits a stronger wettability response and higher recovery improvement than the heavier oil. A positive correlation between WI and ORF confirms wettability alteration as the dominant enhanced oil recovery mechanism. These findings provide a significant contribution by establishing crude oil characteristics as a key controlling factor in nanofluid EOR design, which is crucial for field applications with complex fluid variations.

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