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Lia Yunita
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INDONESIA
Jurnal Offshore: Oil, Production Facilities, and Renewable Energy
Published by Universitas Proklamasi 45 Yogyakarta
ISSN : -     EISSN : 25498681     DOI : 10.30588
Core Subject : Science, Engineering,
Earth & Planetary Sciences Energy Engineering Mechanical Engineering
Jurnal Offshore: Oil, Production Facilities and Renewable Energy is a blind peer-reviewed National Journal in Indonesia and English languages published two issues per year (in June and December). Jurnal Offshore: Oil, Production Facilities, and Renewable Energy focus on providing a publishing platform for scientists and academicians to promote, share, publish and discuss to all aspects of the latest outstanding development in the field of Petroleum Engineering. It encompasses the engineering of oil, production facilities and renewable energy, but it is not limited to scopes. Those are allowed to discuss on the following scope: Oil : geology geophysic in petroleum, reservoir, driliing and production in petroleum. Production Facilities : pipe transportation, separator, flowline, manifold. Renewable energy : geologist, geophysic in geothermal, pirolisis. Software Simulation in Petroleum and Geothermal : CMG, PIPESIM, MFrac, Petrasim, Aspen.
Arjuna Subject : Energi (semua kategori) - Teknik Energi dan Teknologi Daya
Articles 98 Documents
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Transformasi Industri Hulu Migas Menuju Energi Bersih: Studi Literatur Tantangan dan Strategi Implementasi Carbon Capture and Storage di Indonesia Farsya Fatihatul Nizma Tatuhey; Havidh Pramadika; Mulia Ginting; Lisa Samura
Jurnal Offshore: Oil, Production Facilities and Renewable Energy Vol. 9 No. 2 (2025): Jurnal Offshore: Oil, Production Facilities and Renewable Energy
Publisher : Universitas Proklamasi 45

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.30588/jo.v9i2.2627

Abstract

The upstream oil and gas industry is under global pressure to reduce carbon emissions while maintaining production levels. One of the key technologies projected to play a vital role in this energy transition is Carbon Capture and Storage (CCS). This technology captures carbon dioxide (CO₂) emissions from industrial activities and stores them in underground geological formations, including depleted oil and gas reservoirs. Indonesia, as an oil-producing G20 member, has a significant opportunity to develop CCS due to the availability of geological formations suitable for carbon storage. This study aims to identify the potential, challenges, and implementation strategies of CCS in Indonesia’s upstream oil and gas sector through a literature review and conceptual analysis approach. The findings indicate that CCS implementation could support Indonesia’s Net Zero Emission 2060 target, although challenges remain in terms of financing, regulatory framework, and technological readiness. Strategic efforts such as policy strengthening, cross-sector collaboration, and human capital development are essential to accelerate CCS deployment.
Studi Laboratorium Analisis Penambahan CaCO3 pada Berbagai Temperatur terhadap Lumpur Pemboran Sheren Gevani; Sahrudding; Daniel Sinurat
Jurnal Offshore: Oil, Production Facilities and Renewable Energy Vol. 9 No. 2 (2025): Jurnal Offshore: Oil, Production Facilities and Renewable Energy
Publisher : Universitas Proklamasi 45

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.30588/jo.v9i2.2494

Abstract

In this research, the effect of temperature on drilling mud with and without the addition of CaCO₃ was analyzed. The objectives of this study were to determine the changes in mud weight, rheology, filtrate volume, and pH under three temperature variations: 80°F, 130°F, and 180°F for original mud, 3% CaCO₃, and 5% CaCO₃ formulations. Laboratory-scale experiments were conducted. The results showed that mud weight decreased with increasing temperature in all formulations. The mud without CaCO₃ decreased from 9.32 ppg to 7.9 ppg. With 3% CaCO₃, mud weight decreased from 10 ppg to 9.13 ppg, while 5% CaCO₃ showed a reduction from 10.28 ppg to 9.83 ppg. Rheological properties including plastic viscosity (PV), yield point (YP), and gel strength (GS) decreased with temperature increases. Filtrate volume increased at higher temperatures for all mud variations. Meanwhile, pH decreased from 80°F to 130°F but remained constant afterward. Overall, the addition of CaCO₃ improved mud performance but temperature significantly influenced mud properties.
Pengaruh Salinitas dan Konsentrasi Polimer Carboxymethyl Cellulose Terhadap Viskositas dan Adsorpsi pada Formasi Batu Pasir Brian Adisty Kurniawan S Toripalu; Raul Ferdy Ramadani N; Daniel Sinurat
Jurnal Offshore: Oil, Production Facilities and Renewable Energy Vol. 9 No. 2 (2025): Jurnal Offshore: Oil, Production Facilities and Renewable Energy
Publisher : Universitas Proklamasi 45

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.30588/jo.v9i2.2498

Abstract

Enhanced Oil Recovery (EOR) is an advanced oil recovery method used to increase oil production from reservoirs after primary and secondary recovery stages are no longer able to produce oil optimally. Therefore, this study aims to analyze the effect of salinity and Carboxymethyl Cellulose (CMC) solution concentration variations on viscosity and adsorption characteristics in sandstone formations as part of evaluating the potential application of polymers in polymer injection methods in Enhanced Oil Recovery (EOR) technology. The research method was carried out through compatibility testing, viscosity measurement, and adsorption testing using CMC solutions at several variations of concentration and salinity levels with 50 mesh sandstone media. The results showed that an increase in salinity caused a decrease in the viscosity of the CMC solution. At a salinity of 5000 ppm, the viscosity was 4 cP, 4.82 cP, and 16.02 cP at concentrations of 5000 mg/L, 7500 mg/L, and 10000 mg/L, respectively. while at a salinity of 10,000 ppm, it decreased to 2.95 cP, 4.59 cP, and 10.07 cP. In the adsorption test, the adsorption value increased with increasing concentration and salinity. The adsorption values at a salinity of 5000 ppm were 5.13 mg/g, 7.63 mg/g, and 8.46 mg/g, respectively, while at a salinity of 10000 ppm, they increased to 6.32 mg/g, 9.36 mg/g, and 10.61 mg/g.
Analisis Keekonomian pada Produksi Lapangan “RF” Menggunakan Skema Production Sharing Contract (PSC) Cost Recovery Ni Ketut Krisdayanti; Fathul Adawiyah; Daniel Sinurat
Jurnal Offshore: Oil, Production Facilities and Renewable Energy Vol. 9 No. 2 (2025): Jurnal Offshore: Oil, Production Facilities and Renewable Energy
Publisher : Universitas Proklamasi 45

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.30588/jo.v9i2.2501

Abstract

Reserve estimation and economic analysis are essential components in oil and gas field development to determine production feasibility. This study aims to evaluate production reserves and economic performance of the “RF” Field in the “R27” and “A10” reservoirs using the Production Sharing Contract (PSC) Cost Recovery scheme. Reserve estimation and production forecasting were conducted using Decline Curve Analysis (DCA) through MBAL software, while the economic evaluation was performed using Microsoft Excel based on the PSC Cost Recovery fiscal parameters. This study also examines factors influencing economic value and projects future cumulative production under two development scenarios. The results indicate cumulative production of 75.3255 MMSCF for the “R27” reservoir and 89.3819 MMSCF for the “A10” reservoir. The economic analysis shows a Net Present Value (NPV) of 5,276.97 MUSD and an Internal Rate of Return (IRR) of 1665.13%, with a Pay Out Time (POT) of one year. These results indicate that the development of the “RF” Field is economically feasible and suitable for continued production
Evaluasi Surveillance Performa Waterflooding dengan Pendekatan Chan's Diagnostic Plot Rahajeng Rahmadhini; Suranto; Karina Larasati; Dimas Suryo Wicaksono
Jurnal Offshore: Oil, Production Facilities and Renewable Energy Vol. 9 No. 2 (2025): Jurnal Offshore: Oil, Production Facilities and Renewable Energy
Publisher : Universitas Proklamasi 45

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.30588/jo.v9i2.2603

Abstract

Declining oil production as reservoir pressure decreases occurs because the reservoir's natural driving force is no longer able to force to the production well from porous permeable formation. The decline in oil production and reservoir pressure that occurs in the field over time necessitates the implementation of a second-stage oil recovery method (secondary recovery) that can replace the initial method (primary recovery). Secondary recovery method used in this study is water injection, or waterflooding. The objective of this research was to conduct a surveillance analysis of the waterflooding operation using the Chan's Diagnostic Plot approach to determine the connectivity between the wells involved in the operation. Water injection was implemented in oil reservoir in Field “RR” in 1995, and a second production peak was achieved in 1999 with an injection rate of 1,843 bwpd. water injection performance analysis in this study was carried out on the T-070T injection well against 2 production wells T-050 and T-111 using the Chan's Diagnostic approach to determine the connectivity between the waterflood impacted wells. Channeling was observed in that wells during waterflooding. This anaylsis indicates flow connectivity between the well T-070T and T-050/T-111
Carbon Dioxide (CO2) Injection Planning Using Reservoir Simulation: A Review Dedi Kristanto; Hariyadi; Aditya Kurniawan; Eko Widi Pramudyohadi; Unggul Setiadi Nursidik; Muhammad Iqbal Arizzqi Nuzli; Fadli Ramdhani
Jurnal Offshore: Oil, Production Facilities and Renewable Energy Vol. 10 No. 1 (2026): Jurnal Offshore: Oil, Production Facilities and Renewable Energy
Publisher : Universitas Proklamasi 45

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.30588/jo.v10i1.2580

Abstract

Carbon dioxide (CO2) injection planning using reservoir simulation has become a significant method in improving oil recovery (EOR) and simultaneously reducing CO2 emissions to the environment. CO2 injection divided into two mechanism, immiscible and miscible injection, both of which depend on the injection pressure as well as reservoir characteristics. This study reviews various CO2 injection mechanisms and their effectiveness through reservoir simulations. In CO2 injection, a compositional reservoir simulation is used that takes into account the hydrocarbon composition and its equation in pressure, volume, temperature (PVT) analysis. The simulation was used to evaluate the storage capacity, CO2 migration, and optimize the injection strategy. Results show that CO2 injection can increase oil recovery, especially in tight reservoirs. Reservoir simulation provides a deeper understanding of reservoir behavior post-CO2 injection and enables more optimal planning in maximizing hydrocarbon recovery. Overall, this study emphasizes the importance of using reservoir simulation in CO2 injection planning and optimization. With the right approach, this technology can significantly increase oil recovery while aiding climate change mitigation through underground CO2 storage.
Influence of Depositional Environment on Source Rock Potential: A Case Study of Fluvio-Estuarine Sediments in the Lower Tanjung Formation, Martapura Area, Barito Basin, South Kalimantan Sugeng Widada; Mochammad Prahastomi; Muchammad O.B. Nugroho; Aga Rizky; Rizkianto .; Istiana .; Desi K. Isnani
Jurnal Offshore: Oil, Production Facilities and Renewable Energy Vol. 10 No. 1 (2026): Jurnal Offshore: Oil, Production Facilities and Renewable Energy
Publisher : Universitas Proklamasi 45

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.30588/jo.v10i1.2686

Abstract

ABSTRACT The Tanjung Formation in the Barito Basin, South Kalimantan, is a proven hydrocarbon-bearing interval; however, its source rock potential and controlling factors remain uncertain in the Martapura area. This study evaluates the influence of depositional environment on source rock quality, hydrocarbon generation potential, and thermal maturity within fluvio-estuarine sediments of the Lower Tanjung Formation. An integrated approach combining field observations, facies analysis, palynology, and geochemical data (TOC, Rock-Eval pyrolysis, and vitrinite reflectance) was applied to 49 samples from 11 locations. The formation is characterized by a transgressive, upward-fining succession of shale, mudstone, coal, and minor sandstone, deposited in fluvio-estuarine settings including floodplains, swamps, interdistributary bays, and oxbow lakes during the Late Eocene. Geochemical results show highly variable organic richness (TOC <0.5% to >70%) and hydrogen index (HI <100 to >500 mg HC/g TOC), indicating heterogeneous source rock quality in the Lower Tanjung Formation. Coal and coaly shale facies exhibit excellent oil-prone potential, whereas most mudstone and claystone facies are poor to moderate source rocks. Vitrinite reflectance values (Ro 0.38–0.46%) indicate immature thermal conditions. Our findings suggest that the coals in the study area constitute oil-prone source rocks characterized by very high TOC and HI values, and are interpreted to have been deposited in freshwater lacustrine to reducing floodplain environments associated with meandering river systems and oxbow lake development. Despite the presence of high-quality source facies, their limited thickness and lateral extent significantly restrict overall hydrocarbon generation potential.
A Comparative Review of Ancillary Service Markets: Benchmarking Global Practices and Implications for Indonesia Indri Haryani; Valensi Erza; Hendri Bhirowo
Jurnal Offshore: Oil, Production Facilities and Renewable Energy Vol. 10 No. 1 (2026): Jurnal Offshore: Oil, Production Facilities and Renewable Energy
Publisher : Universitas Proklamasi 45

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.30588/jo.v10i1.2750

Abstract

The rapid integration of renewable energy sources is transforming power system operations, resulting in reduced system inertia and increased operational variability. These modifications increase the demand for advanced ancillary service (AS) to ensure system stability, including frequency regulation, reserve provision, and voltage management. Unlike countries that have implemented market-based ancillary services and advanced technologies, Indonesia still operates ancillary services through centralized mechanisms with limited participation of new technologies. This report presents a comparative analysis of the development of ancillary service in selected countries by assessing aspects of market structure, pricing mechanisms, technology integration, regulatory frameworks, and operational maturity. A qualitative maturity assessment methodology is used to evaluate the level of implementation across various power systems. The findings reveal significant differences between developed and developing systems. Countries such as Australia, the United Kingdom, and the United States demonstrate more advanced maturity by incorporating rapid response technologies, competitive market frameworks, and real-time system operations. In contrast, Indonesia is still at an early stage with centralized management, limited technology integration, and the absence of a structured ancillary service market. Unlike existing comparative studies focused on OECD contexts, this paper explicitly targets the policy and implementation gap for a large, archipelagic, state utility dominated emerging economy. A five phase implementation roadmap is proposed for 2025–2034, aligned with RUPTL targets and calibrated to Indonesian institutional realities.

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