scholarly journals Rekayasa Nilai Kriteria Desain Fasilitas Produksi Gas Alam

2021 ◽  
Vol 6 (2) ◽  
pp. 120-134
Author(s):  
Hibrah Hibrah ◽  
Sutrasno Kartohardjono ◽  
Mohammed Ali Berawi
Keyword(s):  
Natural Gas ◽  
Net Present Value ◽  
Capital Expenditure ◽  
Hydrocarbon Composition ◽  
Comparison Method ◽  
Gas Production ◽  
Design Criterion ◽  
Production Unit ◽  
The North ◽  
Offshore Production

Natural gas is one of the primary hydrocarbon energies in Indonesia. The construction of natural gas production facilities is essential to accommodate domestic energy needs. These facilities include production, pipelines, and processing facilities in an integrated manner. This study used the hydrocarbon composition of Field-X with an average of 7.62% CO2 and 0.06% H2S. The alternative design uses a fixed platform (fixed platform), MOPU (Mobile Offshore Production Unit), and a Semi-Submersible platform. The design comparison criteria are capital expenditure (CapEx), net present value (NPV), internal rate of return (IRR), work completion time, safety risk, and flexibility of future facility development. Through the comparison method, it is found that Option A is the best option, which has a design criterion value of 57%, a higher NPV of $43,537,469.58 than the smallest NPV option, an IRR of 19%, and a payout time (POT) of 5 years. Option A uses a fixed platform with a pipeline to the north, the hydrocarbon separation process is carried out on an offshore platform, and the processing is carried out onshore. ABSTRAKGas alam merupakan salah satu energi hidrokarbon utama di Indonesia. Pembangunan fasilitas produksinya sangat penting untuk mengakomodasi kebutuhan energi dalam negeri. Fasilitas ini meliputi produksi, jalur pemipaan, dan fasilitas pengolahan hidrokarbon secara terintegrasi. Penelitian ini menggunakan komposisi hidrokarbon dari Lapangan-X dengan rata-rata CO2 7.62% dan H2S 0.06%. Alternatif desain menggunakan anjungan tetap (fix platform), MOPU (Mobile Offshore Production Unit), dan anjungan Semi-Submersible. Kriteria perbandingan desain adalah modal awal, nilai bersih saat ini (NPV), tingkat pengembalian internal (IRR), waktu penyelesaian pekerjaan, resiko keselamatan, dan flexibilitas pengembangan fasilitas kedepan. Melalui metode perbandingan yang dipadankan didapatkan Opsi A  adalah opsi terbaik, yang memiliki nilai kriteria desain 57%, NPV lebih tinggi $43,537,469.58 dibanding opsi NPV terkecil, IRR 19% dan waktu pembayaran (payout time/POT) 5 tahun. Opsi A  menggunakan anjungan tetap dengan jalur pemipaan ke arah Utara, proses separasi hidrokarbon dilakukan pada anjungan lepas pantai (offshore) dan pengolahannya dilakukan di darat (onshore). 

Distribution and estimates of Australia's identified energy commodity resources

2021 ◽  
Vol 61 (2) ◽  
pp. 325
Author(s):  
Barry E. Bradshaw ◽  
Meredith L. Orr ◽  
Tom Bernecker
Keyword(s):  
Natural Gas ◽  
Carbon Capture ◽  
Coal Gasification ◽  
Carbon Capture And Storage ◽  
Energy Resource ◽  
Gas Production ◽  
Renewable Energy Resources ◽  
North West ◽  
The North ◽  
Energy Provider

Australia is endowed with abundant, high-quality energy commodity resources, which provide reliable energy for domestic use and underpin our status as a major global energy provider. Australia has the world’s largest economic uranium resources, the third largest coal resources and substantial conventional and unconventional natural gas resources. Since 2015, Australia’s gas production has grown rapidly. This growth has been driven by a series of new liquefied natural gas (LNG) projects on the North West Shelf, together with established coal seam gas projects in Queensland. Results from Geoscience Australia’s 2021 edition of Australia’s energy commodity resources assessment highlight Australia’s endowment with abundant and widely distributed energy commodity resources. Knowledge of Australia’s existing and untapped energy resource potential provides industry and policy makers with a trusted source of data to compare and understand the value of these key energy commodities to domestic and world markets. A key component of Australia’s low emissions future will be the development of a hydrogen industry, with hydrogen being produced either through electrolysis of water using renewable energy resources (‘green’ hydrogen), or manufactured from natural gas or coal gasification, with carbon capture and storage of the co-produced carbon dioxide (‘blue’ hydrogen). Australia’s endowment with abundant natural gas resources will be a key enabler for our transition to a low emissions future through providing economically competitive feedstock for ‘blue’ hydrogen.

US gas pipeline shortage may drive energy diversity

2015 ◽  
Keyword(s):  
Natural Gas ◽  
Gulf Coast ◽  
Gas Production ◽  
Gas Pipeline ◽  
South Texas ◽  
Content Type ◽  
North West ◽  
Natural Gas Pipeline ◽  
North East ◽  
The North

Subject The effects of natural gas pipeline supply constraints in the US North-east. Significance The shale 'revolution' has caused a sharp rise in US natural gas production, but it has been located in areas without gas infrastructure. Production has been concentrated along the Gulf Coast, and the pipeline network is oriented from that region to the North-east and Pacific North-west. Newer areas of energy production, such as Bakken in North Dakota, Eagle Ford in South Texas, and Marcellus in Appalachia, have poor connections to major markets, and constraints have led to pricing spikes in the North-east. Impacts The majority of proposed pipelines for the next several years target areas in the upper Midwest, Mid-Atlantic, and South-east markets. Manufacturers in the North-east will face competitive disadvantage from paying the highest energy costs in North America. Pipeline constraints will not dampen enthusiasm for liquefied natural gas (LNG) exports, especially out of West Coast ports.

scholarly journals Dual hydrocarbon–geothermal energy exploitation: potential synergy between the production of natural gas and warm water from the subsurface

2019 ◽  
Vol 98 ◽  
Author(s):  
Jeroen van der Molen ◽  
Elisabeth Peters ◽  
Farid Jedari-Eyvazi ◽  
Serge F. van Gessel
Keyword(s):  
Natural Gas ◽  
Financial Risk ◽  
Net Present Value ◽  
Gas Production ◽  
Added Value ◽  
Reservoir Properties ◽  
Gas Field ◽  
Gas Recovery ◽  
Water Breakthrough ◽  
High Standards

Abstract The decline of domestic natural gas production, increasing dependency on gas imports and lagging development of renewable energy production may pose serious challenges to the current high standards of secure energy supply in the Netherlands. This paper examines synergy between hydrocarbon- and geothermal exploitation as a means to reinforce energy security. The Roden gas field is used as an example to demonstrate potential delay of water breakthrough in the gas well and a resulting increase of recovered gas (up to 19%), by positioning of a geothermal doublet in the water leg of the gas field. The reservoir simulations show that the total increase of gas production primarily depends on the amount of aquifer support. An optimal configuration of gas- and geothermal wells is key to maximise gas recovery and strongly depends on the distribution of reservoir properties. The study also reveals that this option can still be beneficial for gas fields in a late stage of production. Net Present Value calculations show that the added value from the geothermal doublet on total gas production could lead to an early repayment of initial investments in the geothermal project, thereby reducing the overall financial risk. If no subsidies are taken into account, the additional profits can also be used to finance the geothermal project up to break-even level within 15 years. However, this comes with a cost as the additional profits from improved gas recovery are significantly reduced.

scholarly journals PROJECTS DE DEVELOPED WITH RESOURCES OF THE CT-PETRO SECTOR FUND IN THE NORTH, NORTHEAST AND CENTRAL-WEST REGIONS

2021 ◽  
Vol 9 (7) ◽  
pp. 305-322
Author(s):  
Rosa Elaine Andrade Santos ◽  
Gabriel Francisco da Silva ◽  
Josenito Oliveira Santos ◽  
José Ricardo de Santana ◽  
Cleide Mara Barbosa da Cruz
Keyword(s):  
Natural Gas ◽  
Technological Innovation ◽  
Patent Application ◽  
Information Service ◽  
Gas Production ◽  
Industrial Property ◽  
Production Chain ◽  
Natural Gas Production ◽  
The North ◽  
Oil And Natural Gas

The present work aims to analyze the development of projects with resources from CT-Petro; since its creation. This Sectorial Fund envisioned the technological development of the Oil and Natural Gas production chain in the North, Northeast and Midwest regions. This study sought to survey the actions of the projects developed and whether patents were somehow created with the financial resources released through FINEP for the realization of CT-Petro. The unfolding of the activities was carried out with the application of questionnaires to public institutions registered in the Electronic System of the Citizen Information Service – e-Sic-CGU. From the tabulation of the information collected from the sample, the direction given was to compare with the information from the patent application filing database, of the National Institute of Industrial Property - INPI, in order to identify the percentage values of filing applications of these three regions and how the Sectoral Fund has impacted the development of patents and their respective application for protection. The survey carried out showed that even after the implementation of CT-Petro there was little change in the national scenario of IP productivity, aimed at the Oil and Natural Gas production chain, in Brazilian territory. This research is qualitative and quantitative, with the application of a semi-open questionnaire and data collection on INPI database websites, technological innovation agency websites, technological innovation centers, scientific journals, dissertations, theses and access platform information from the Brazilian Federal Government.

‘Back to the Future' A review of Australian reservation and other natural gas export control policies

2019 ◽  
Vol 59 (2) ◽  
pp. 505
Author(s):  
James Plumb
Keyword(s):  
Natural Gas ◽  
Gas Production ◽  
Export Market ◽  
North West ◽  
The North ◽  
History Of ◽  
Gas Market ◽  
The Government ◽  
Regulatory Controls ◽  
Land Reserve

Despite record levels of domestic production, forecasters are predicting that the east coast Australian gas market will remain tight in 2019. The introduction of the Australian Domestic Gas Security Mechanism (ADGSM) by the Federal Government in 2017, and the proposal announced by the Australian Labour Party (ALP) to bolster the mechanism, have again thrust the issue of political intervention in the export gas market into sharp focus. This paper provides an overview of the current regulatory intervention at the state and federal level, and looks back at the history of controls imposed upon the Australian gas export market. The paper is divided into two parts: Part 1, which looks at current regulatory controls engaged by various State and Federal governments: (a) the development and implementation of the ADGSM; (b) the development and implementation of the Queensland Government’s Prospective Gas Production Land Reserve policy (PGPLR); and (c) the Government of Western Australia’s (WA Government) domestic gas policy. The paper also reviews policy announcements made by the ALP in the lead up to the 2019 Federal election. Part 2 provides a broad overview of the history of controls on gas exports in Australia, from the embargo on exports from the North West Shelf between 1973 and 1977, through the increasing liberalisation of Australian energy policy during the 1980s and 1990s (and the associated conflict with state concerns of ensuring sufficiency of the domestic supply of gas), up to the removal of federal controls on resources exports (including liquefied natural gas) in 1997.

scholarly journals Economic and Technological Analysis of Commercial LNG Production in the EU

Energies ◽  
2019 ◽  
Vol 12 (8) ◽  
pp. 1565 ◽  
Author(s):  
Vladimír Hönig ◽  
Petr Prochazka ◽  
Michal Obergruber ◽  
Luboš Smutka ◽  
Viera Kučerová
Keyword(s):  
Natural Gas ◽  
Energy Security ◽  
Net Present Value ◽  
Gas Production ◽  
Liquefied Natural Gas ◽  
Small Scale ◽  
Present Value ◽  
Alternative Sources ◽  
Technological Analysis ◽  
The Eu

There is a global need to increase the production of alternative sources of energy due to many issues related to conventional sources, such as environmental degradation or energy security. In this paper, decentralized liquefied natural gas production is analyzed. Liquefied natural gas, according to the analysis, can be considered a viable alternative even for decentralized applications Design and economic analysis of a small-scale biogas LNG plan together with the necessary technology and economic evaluation are presented in the paper. The results show that a project of the proposed size (EUR 3 million) offers a relatively good profitability level. Specifically, the net present value of the project is mostly positive (around EUR 0.1 million up to EUR 0.8 million). Therefore, based on the research, small LNG plants operating across the continent can be recommended for the processing of local sources of biogas.

scholarly journals Industrial production of natural gas in the North and Arctic regions of the Russian Federation and prospects for its implementation in the EU market

2020 ◽  
Vol 84 ◽  
pp. 03005
Author(s):  
Mikhail Ulchenko
Keyword(s):  
Natural Gas ◽  
Russian Federation ◽  
Industrial Production ◽  
Gas Production ◽  
Yamal Peninsula ◽  
The European Union ◽  
Eu Countries ◽  
The North ◽  
The Russian Federation ◽  
The Eu

The paper is devoted to the study of industrial production of natural gas in the regions of the North and Arctic of the Russian Federation and the prospects for its implementation in the market of the European Union. It is shown that the main production is concentrated in the Yamal-Nenets Autonomous district, where up to 75% of the total gas production is produced. Gas is transported both by means of a well-developed pipeline network connecting the Yamal Peninsula with European countries, and in a liquefied state, using gas carriers of the appropriate ice class. At the same time, despite all the efforts of the EU countries to reduce energy consumption, gas consumption is growing. This is due to the decline in production within the Union itself, as well as the desire to use more environmentally friendly energy sources. The analysis conducted in the course of the study showed that Qatar and Russia can actually increase the volume of deliveries in the near future. These exporters have a number of advantages that, in our opinion, will allow them to increase their presence in the energy market of the EU countries - significant reserves of natural gas, availability of production capacity, opportunities to increase the volume of transportation, and the most attractive price for end users.

scholarly journals HYDRATE MITIGATION FOR DEEP WATER AND LONG DISTANCE PIPELINE – FLOW ASSURANCE APPROACH

2015 ◽  
Vol 38 (2) ◽  
pp. 95-104
Author(s):  
Riesto Mundi Karono
Keyword(s):  
Natural Gas ◽  
Oil And Gas ◽  
Gas Production ◽  
Continental Margins ◽  
Long Distance ◽  
Oil And Gas Production ◽  
Software Application ◽  
Offshore Production ◽  
Oil Pipelines ◽  
Mitigation Methods

The existence of gas hydrates is well known in the oil and gas production industry. The components are dominated by methane and naturally occur in deep marine sediment along continental margins. Although hydrates may be of potential benefi t both as a hydrocarbon resource and as a mean of storing and transmitting natural gas, traditionally their presence is considered to be an operational and a safety problem. They can form at the pressures and temperatures found in natural gas and oil pipelines causing blockages, especially when temperature falls signifi cantly, such as when closing in a well or fl owing gas through a choke. This could deliver a serious potential problem for oil and gas offshore production either for its equipment or personnel. Besides the variation of gas rate to avoid hydrates forming, currently there are two methods that have been used widely to prevent hydrates formation in production pipelines - thermal insulation and chemical inhibitor. Each method has its own benefits. PIPESIM software application can be used to evaluate both mitigation methods and to then fi nd which is the best scenario based on lowest cost, shortest period of application and less adversity.

Turkmenistan's gas dependence on China is risky

2015 ◽  
Keyword(s):  
Natural Gas ◽  
Gas Production ◽  
Export Diversification ◽  
Diversification Strategy ◽  
Content Type ◽  
Seasonal Peak ◽  
The North ◽  
Gas Markets ◽  
Industrial Demand

Subject Turkmenistan's gas markets. Significance On February 4, Russian Gazprom's Deputy CEO Alexander Medvedev announced that his company intended to reduce natural gas imports from Turkmenistan, from about 10 billion cubic metres (bcm) in 2014, to just 4 bcm in 2015. Ashgabat has not reacted officially so far, but a Turkmenistani government source recently characterised Gazprom as an "unreliable partner". Gazprom's move highlights the challenges of Turkmenistan's export diversification strategy, at a time when it is in the process of ramping up gas output to meet growing demand, particularly from China. Impacts Although gas prices have declined since 2014, Turkmenistan's finances are not affected, as it sells gas under long-term contracts. Afghanistan's deteriorating security may jeopardise Turkmenistan's gas production, as most fields, including Galkynysh, are in the south. Gas exports to Iran are likely to remain stable, as Tehran is incapable of satisfying both seasonal peak and industrial demand in the north. China's transition from an economy based on coal to gas will spur future demand for Turkmenistani gas.

“Shale Gas Revolution”: Myths and Realities

2013 ◽  
pp. 3-13
Author(s):  
N. Simoniya
Keyword(s):  
Natural Gas ◽  
Shale Gas ◽  
North American ◽  
Gas Production ◽  
Natural Gas Markets ◽  
The North ◽  
The World ◽  
The Usa ◽  
Gas Markets

The author argues that in recent years the world natural gas markets demonstrated vital new trends that primarily relate to the general slump in demand for the natural gas, as well as to accelerated build-up of shale gas production in the North American countries – the USA and Canada. The author proposes a non-partisan analysis of the factors and prospects of the “shale gas revolution”. The general conclusion is that the widely advertised forecasts of the upcoming dislodgement of the traditional gas, including LNG, from the markets of importing nations have no serious grounds.

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