Готові списки джерел за темами / Coal liquefaction Indonesia

Добірка наукової літератури з теми "Coal liquefaction Indonesia"

Автор: Grafiati
Опубліковано: 10 грудня 2022
Оновлено: 28 січня 2023

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Статті в журналах з теми "Coal liquefaction Indonesia"

1

Zetra, Yulfi, Anis Febriati, Dyah Nirmala, Rafwan Year Perry Burhan, Arizal Firmansyah, and Zjahra Vianita Nugraheni. "Low-Calorie Coal Liquefaction Products as an Alternative Fuel Oil." Indonesian Journal of Chemistry 22, no. 6 (November 24, 2022): 1574. http://dx.doi.org/10.22146/ijc.74584.

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Liquefaction of low-rank coal has been done to optimize the utilization of low-rank coal, which is less economical for obtaining alternative fuel oil. Coal samples were taken from the Bukit Pinang coal mine, Samarinda Ulu, East Kalimantan. Coal was liquefied using the NEDOL procedure at PUSPITEK, Serpong, South Tangerang, Indonesia. This Bukit Pinang coal liquefaction produces five fractions consisting of Naphta, Light Oil (LO), Middle Oil (MO), Heavy Oil (HO), and Coal Liquid Bottom (CLB) fractions. The liquefaction yield was dominated by the HO and CLB fractions (> 50% by weight). The naphtha, MO and LO fractions were fractionated using SiO2 GF254 Thin Layer Chromatography (TLC) plate. It produced aliphatic and aromatic hydrocarbon fractions. Aliphatic hydrocarbon fractions were analyzed using a Gas Chromatography-Mass Spectrometer (GC-MS), while the aromatic hydrocarbon fractions were not analyzed. Mass spectrum studies showed that the components consisted of n-alkanes, isoalkanes (branched alkanes), cycloalkanes and alkyl cycloalkanes. The aliphatic hydrocarbon components resulting from the liquefaction of low-rank coal showed its equivalence with the components that make up fuel oil. Therefore, this coal liquefaction can be suggested as an optimization for low-rank coal, which is less economical.
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2

Yanai, S. "Feasibility study on direct coal liquefaction in Indonesia." Fuel and Energy Abstracts 43, no. 4 (July 2002): 244. http://dx.doi.org/10.1016/s0140-6701(02)86140-9.

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3

Yasin, C. M., B. Yunianto, S. Sugiarti, and G. K. Hudaya. "Implementation of Indonesia coal downstream policy in the trend of fossil energy transition." IOP Conference Series: Earth and Environmental Science 882, no. 1 (November 1, 2021): 012083. http://dx.doi.org/10.1088/1755-1315/882/1/012083.

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Abstract The implementation of downstream coal policies in Indonesia is regulated in Law Number 3 of 2020 to optimize coal’s domestic use and value-added. The policy is also supported by the issuance of fiscal, non-fiscal, and regional incentives. In Law Number 3 of 2020, the government of Indonesia states six types of coal downstream: coal upgrading; coal briquetting; cokes making; coal liquefaction; coal gasification; and coal slurry, yet the government has not defined which downstream coal products should be prioritized. Several parameters must be considered in implementing the downstream coal policy, those are the availability of coal and its characteristics, proven technology, economic and environmental feasibility. This study examines the mineral and coal sector regulation, taxation, coal resources and reserves, technology, and economics. In addition, to implement the commitment of reducing CO2 emissions, this study also considers applying Carbon Capture and Storage (CCS) or Carbon Capture, Utilization, and Storage (CCUS) technology to implement downstream coal policy.
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4

KANEKO, Takao, Eiichiro MAKINO, Satoru SUGITA, Motoharu YASUMURO, Noriyuki OKUYAMA, Masaaki TAMURA, Katsunori SHIMASAKI, and Lambok H. SILALAHI. "Development of Limonite Catalyst for Direct Coal Liquefaction. 2. Properties and Liquefaction Activities of Nickel Containing Limonite Ores in Indonesia." Journal of the Japan Institute of Energy 80, no. 10 (2001): 953–62. http://dx.doi.org/10.3775/jie.80.953.

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5

Singh, P. K., M. P. Singh, A. K. Singh, M. Arora, and A. S. Naik. "The Prediction of the Liquefaction Behavior of the East Kalimantan Coals of Indonesia: An Appraisal through Petrography of Selected Coal Samples." Energy Sources, Part A: Recovery, Utilization, and Environmental Effects 35, no. 18 (September 17, 2013): 1728–40. http://dx.doi.org/10.1080/15567036.2010.529731.

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6

Ulchenko, Michael V. "ANALYSIS OF LNG MARKET TRENDS AND PROSPECTS FOR THE IMPLEMENTATION OF RUSSIAN ARCTIC LNG PROJECTS." Север и рынок: формирование экономического порядка 71, no. 1/2021 (March 16, 2021): 83–99. http://dx.doi.org/10.37614/2220-802x.1.2021.71.007.

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Анотація:
Currently, natural gas is considered by most countries as the main source of energy, since it is the cleanest of all hydrocarbon fuels. So, the countries of the European Union have already announced their intention to completely abandon coal, in the production of electricity, in favor of natural gas by 2030. A similar policy is being pursued by the countries of the Asia-Pacific region, although they do not specify any specific deadlines. At the same time, natural gas is transported in two ways — using a pipeline and in liquefied form. The main advantage of the second method is that after liquefaction, the gas can be delivered to any point of the planet where there is a demand for it. Currently, the growth rate of the liquefied natural gas market is such that in 15–20 years it will not only catch up with the pipeline market, but also surpass it The paper identifies the key producers and exporters of liquefied natural gas, as well as assesses their potential opportunities in terms of increasing the volume of natural gas production and LNG production. The analysis showed that at the beginning of 2021, the main LNG exporters are Australia, Algeria, Indonesia, Malaysia, Qatar, Nigeria, Russia and the United States. At the same time, Qatar, Russia and the United States have real opportunities to increase export volumes. Australia is also able to increase production volumes, as it has reserves and spare production capacity, but due to the significantly increased domestic demand for LNG, it is likely that it will not be able to do this in the near future.
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7

YOON, W., G. JIN, Y. KIM, I. CHOI, and W. LEE. "Statistical study of the liquefaction of an Indonesian subbituminous coal." Fuel 68, no. 5 (May 1989): 614–17. http://dx.doi.org/10.1016/0016-2361(89)90160-9.

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8

Artanto, Y., W. R. Jackson, P. J. Redlich, and M. Marshall. "Liquefaction studies of some Indonesian low rank coals." Fuel 79, no. 11 (September 2000): 1333–40. http://dx.doi.org/10.1016/s0016-2361(99)00275-6.

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9

Dewita, E., R. Prassanti, K. S. Widana, and Y. S. B. Susilo. "Cost Analysis of Nuclear Hydrogen Production Using IAEA-HEEP 4 Software." Journal of Physics: Conference Series 2048, no. 1 (October 1, 2021): 012005. http://dx.doi.org/10.1088/1742-6596/2048/1/012005.

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Abstract Hydrogen is a commercially important element. Basically, there are several methods of hydrogen production that have been commercially used, such as Steam Methane Reforming (SMR), High Temperature Steam Electrolysis (HTSE), and thermochemical cycles, like Sulphur-Iodine (SI). Among these methods, SMR is the most widely used for large-scale hydrogen production, with conversion efficiency between 74–85% and it has commercially used in some fertilizer industries in Indonesia. Steam reforming is a method to convert alkane (natural gas) compounds to hydrogen and carbon dioxide (synthetic gas) by adding moisture at high pressure and temperature (35-40 bar; 800-900°C). These hydrogen production technologies can be coupled with different nuclear reactors based on the heat required in the process. The High Temperature Gas-cooled Reactor (HTGR) using helium as a coolant, has a high outlet temperature (900°C), so it can potentially be used to supply for process heat for hydrogen production, coal liquefaction/gasification or for other industrial processes requiring high temperature heat. Hydrogen production cost from SMR method is influenced by a range of technical and economic factors. The fuel component of natural gas needed in the SMR method can be replaced by nuclear heat from a nuclear power plant (NPP) operating in cogeneration mode (i.e. simultaneous producing electric power and heat), hence contributing to the reduction of carbon dioxide in the process. In the SMR method, fuel costs are the largest cost component, accounting for between 45% and 75% of production costs. Therefore, there is opportune to assess the economics of hydrogen production by using nuclear heat. The economic evaluation is done by using IAEA HEEP-4 Software. The results comprise cost break up for 2 cases, coupling SMR process for hydrogen production with: (1) 2 HTGRs of 170 MWth/unit; and (2) 1 HTGR of 600 MWth/unit. The cost of hydrogen production is highly depend on the scale of the NPP as energy source and results indicated that hydrogen production cost of the 1 HTGR Unit600 MWth (Case 2) has a lower value (1.72 US$/kgH2), than the cost obtained when 2 HTGR units of 170 MWth each (case 1) are considered (2.72 US$/kgH2). For comparison, the hydrogen production cost by using SMR with carbon capture and storage (CCS) with natural gas as fuel is 2.27 US$/kgH2.
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10

Soelistijo, Ukar Wijaya. "The Potential Share of Coal Liquefaction in the Indonesian Economy in 2025." Earth Sciences 2, no. 6 (2013): 149. http://dx.doi.org/10.11648/j.earth.20130206.16.

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