cover
Article Per Year (5 Year)
All
Home Page
OAI Link
Editorial Team
Contact
Reviewer
Google Scholar
Contact Name
Wulandari
Contact Email
jurnal.lemigas@esdm.go.id
Phone
+6221-7394422
Journal Mail Official
jurnal.lemigas@esdm.go.id
Editorial Address
Jl. Ciledug Raya Kav. 109, Cipulir, Kebayoran Lama, Jakarta Selatan 12230
Location
Kota adm. jakarta selatan,
Dki jakarta
INDONESIA
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 683 Documents
 65   66   67   68   69 
A Techno-Economic Framework for Natural Gas Pipeline Tariff Determination Under State Budget Financing: Evidence from The Semarang-Batang Open-Access Transmission Pipeline, Indonesia Aji Agraning Bawono; Sutrasno Kartohardjono
Scientific Contributions Oil and Gas Vol 49 No 2 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i2.2117

Abstract

Natural gas pipeline tariff regulation in Indonesia has historically been designed for investor-financed infrastructure, where tariffs must recover capital costs at a commercially determined weighted average cost of capital (WACC). The Semarang-Batang Transmission Pipeline (Cisem Phase I)—the first open-access transmission pipeline in Indonesia constructed under State Budget (APBN) financing—demands a fundamentally different tariff framework. This study develops and evaluates two alternative tariff formulation models tailored to government-funded infrastructure: (i) the State Capital Participation (PMN) scheme, which recovers capital at the government's retail sukuk coupon rate (IRR = 3.97%), and (ii) the State Property (BMN) scheme, which waives capital recovery entirely and charges only a management fee (CAPEX = 0). Results show that the BMN scheme delivers the lowest tariff of USD 0.279/MSCF, representing 55.7% below the conventional WACC-based tariff (USD 0.630/MSCF) and 25.0% below the PMN scheme (USD 0.372/MSCF). Sensitivity analysis confirms the BMN scheme's structural advantage: it eliminates IRR-driven tariff volatility and maximizes affordability for industrial end-users. These findings provide a replicable techno-economic framework and a practical policy basis for BPH Migas in determining transportation tariffs for APBN-financed pipeline infrastructure across Indonesia.
Effect of Corn Cob Addition on the Rheological and Filtration Properties of Water Based Drilling Mud Apriandi Rizkina Rangga Wastu; Ridha husla; Ghanima Yasmianiar; Asri Nugrahanti; Venezia Chelsea Reggiana Kalalo; R Hari Karyadi Oetomo; Siti Azizah
Scientific Contributions Oil and Gas Vol 49 No 3 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i3.2016

Abstract

Drilling mud is an essential tool in supporting the success of productive and economical oil and gas well drilling activities. Some chemical additives used to enhance the physical and rheological properties of mud tend to be toxic, non-biodegradable, and have negative environmental impacts. The use of household waste materials such as corn cobs, which can be reused as a natural polymer in drilling mud, presents a promising alternative. The separation of these materials serves the purpose of identifying a new type of polymer candidate, as they contain 41.27% cellulose, 46% hemicellulose, and 7.40% lignin, making them suitable for use as a polymer. The research involves analyzing the mud rheology, including plastic viscosity, yield point, gel strength, filtration loss, and mud cake, using three samples of water-based mud containing 1.5 grams, 3 grams, and 4.5 grams of finely ground corn cobs. The samples are then tested at two different temperatures, 80ºF and 200ºF, to observe the behavior of corn cobs when circulated into the well and entering formations with higher temperatures. Changes in rheological values and filtration loss with each additive addition will serve as indicators of the feasibility of corn cobs as a biodegradable alternative additive containing cellulose in drilling mud.
Optimizing CO₂ Storage in Saline Aquifers Through Pressure Redistribution in Natuna D-Alpha Field, Indonesia Roihan Arie Nirwana; Dedy Irawan; Amega Yasutra; Syarif Kamal; Welly Ahmad Ramadan
Scientific Contributions Oil and Gas Vol 49 No 3 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i3.2119

Abstract

The increasing concentration  of carbon dioxide (CO₂) in the atmosphere is significantly contributing to the critical exploration of Carbon Capture and Storage (CCS) technology. Although deep saline aquifers offer substantial storage potential for CO2, their effective capacity is often constrained by rapid formation pressure buildup near injector wells and poses safety risks. Therefore, this study aims to propose an integrated strategy to optimize CO₂ storage capacity using pressure redistribution method in a thick carbonate saline aquifer located in Natuna D-Alpha Field, Indonesia. A dynamic numerical simulation is developed by integrating 2D seismic, well logs, core analysis (RCAL/SCAL), and geomechanical parameters derived from log data. The effectiveness of lateral and vertical pressure redistribution is evaluated through brine production wells (PWs) and multi-depth injection, respectively, followed by perforation configuration optimization.Various scenarios are simulated to compare total gas injected and reservoir pressure response against rock fracture limits. The results showed that storage capacity is limited due to the absence of pressure management (Base Case). The implementation of lateral pressure redistribution through brine production proves to be the most significant strategy, capable of increasing storage capacity by approximately 64% of the Base Case in high-rate production scenarios. Furthermore, vertical redistribution strategy using multi-depth injection obtains a 13% capacity increase and improves vertical pressure distribution. A combination of multi-depth injection and brine production shows positive synergy, generating a 44% capacity increase with a storage efficiency of 0.58%. The results also indicate that variations in well perforation geometric patterns (line vs. cross) have minimal impact compared to global pressure management strategies. In line with the analysis, this study finds that brine extraction and vertical injection management are essential to maximizing safe CO₂ storage in thick aquifers.    

Page 69 of 69 | Total Record : 683

 65   66   67   68   69 

Filter by Year

1982 2026


Reset
Filter By Issues
All Issue Vol 49 No 3 (2026) Vol 49 No 2 (2026) Vol 49 No 1 (2026) Vol 48 No 4 (2025) Vol 48 No 3 (2025) Vol 48 No 2 (2025) Vol 48 No 1 (2025) Vol 47 No 3 (2024) Vol 47 No 2 (2024) Vol 47 No 1 (2024) Vol 46 No 3 (2023) Vol 46 No 2 (2023) Vol 46 No 1 (2023) Vol 45 No 3 (2022) Vol 45 No 2 (2022) Vol 45 No 1 (2022) Vol 44 No 3 (2021) Vol 44 No 2 (2021) Vol 44 No 1 (2021) Vol 43 No 3 (2020) Vol 43 No 2 (2020) Vol 43 No 1 (2020) Vol 42 No 3 (2019) Vol 42 No 2 (2019) Vol 42 No 1 (2019) Vol 41 No 3 (2018) Vol 41 No 2 (2018) Vol 41 No 1 (2018) Vol 40 No 3 (2017) Vol 40 No 2 (2017) Vol 40 No 1 (2017) Vol 39 No 3 (2016) Vol 39 No 2 (2016) Vol 39 No 1 (2016) Vol 38 No 3 (2015) Vol 38 No 2 (2015) Vol 38 No 1 (2015) Vol 37 No 3 (2014) Vol 37 No 2 (2014) Vol 37 No 1 (2014) Vol 36 No 3 (2013) Vol 36 No 2 (2013) Vol 36 No 1 (2013) Vol 35 No 3 (2012) Vol 35 No 2 (2012) Vol 35 No 1 (2012) Vol 34 No 3 (2011) Vol 34 No 2 (2011) Vol 34 No 1 (2011) Vol 33 No 3 (2010) Vol 33 No 2 (2010) Vol 33 No 1 (2010) Vol 32 No 3 (2009) Vol 32 No 2 (2009) Vol 32 No 1 (2009) Vol 31 No 3 (2008) Vol 31 No 2 (2008) Vol 31 No 1 (2008) Vol 30 No 3 (2007) Vol 30 No 2 (2007) Vol 30 No 1 (2007) Vol 29 No 3 (2006) Vol 29 No 2 (2006) Vol 29 No 1 (2006) Vol 28 No 3 (2005) Vol 28 No 2 (2005) Vol 28 No 1 (2005) Vol 27 No 3 (2004) Vol 27 No 2 (2004) Vol 27 No 1 (2004) Vol 26 No 2 (2003) Vol 26 No 1 (2003) Vol 25 No 3 (2002) Vol 25 No 2 (2002) Vol 25 No 1 (2002) Vol 24 No 2 (2001) Vol 24 No 1 (2001) Vol 23 No 3 (2000) Vol 23 No 2 (2000) Vol 23 No 1 (2000) Vol 22 No 2 (1999) Vol 22 No 1 (1999) Vol 21 No 2 (1998) Vol 21 No 1 (1998) Vol 18 No 2 (1995) Vol 18 No 1 (1995) Vol 17 No 1 (1994) Vol 16 No 1 (1993) Vol 15 No 1 (1992) Vol 14 No 2 (1991) Vol 14 No 1 (1991) Vol 13 No 1 (1990) Vol 12 No 1 (1989) Vol 11 No 1 (1988) Vol 10 No 3 (1987) Vol 10 No 2 (1987) Vol 10 No 1 (1987) Vol 9 No 1 (1986) Vol 8 No 2 (1985) Vol 8 No 1 (1985) Vol 7 No 2 (1984) Vol 7 No 1 (1984) Vol 6 No 1 (1983) Vol 5 No 2 (1982) Vol 5 No 1 (1982) More Issue