The groundwater hydrology of underground coal gasification coupled to carbon capture and storage

2010 ◽  
Author(s):  
P.L. Younger ◽  
G. González
Keyword(s):  
Carbon Capture ◽  
Coal Gasification ◽  
Carbon Capture And Storage ◽  
Groundwater Hydrology ◽  
Underground Coal Gasification ◽  
And Storage

Recent developments and current position of underground coal gasification

2017 ◽  
Vol 232 (1) ◽  
pp. 39-46 ◽  
Author(s):  
Michael Green
Keyword(s):  
Carbon Capture ◽  
Coal Gasification ◽  
Academic Research ◽  
Carbon Capture And Storage ◽  
Extraction Process ◽  
Pilot Scale ◽  
The European Union ◽  
Underground Coal Gasification ◽  
Product Gas ◽  
And Storage

Underground coal gasification is a conversion and extraction process, for the production of useful synthetic product gas from an in-situ coal seam, to use in power generation, heat production or as a chemical feedstock. While many variants of the underground coal gasification process have been considered and over 75 trials performed throughout the world, the recent work has tended to focus on the control of the process, its environmental impact on underground and surface conditions and its potential for carbon capture and storage. Academic research has produced a set of mathematical models of underground coal gasification, and the European Union-supported programme has addressed the production of a decarbonised product gas for carbon capture and storage. In recent years, significant progress has been made into the modelling of tar formation, spalling, flows within the cavity and the control of minor gasification components, like BTEX and phenols, from underground coal gasification cavities (BTEX refers to the chemicals benzene, toluene, ethylbenzene and xylene). The paper reviews the most recent underground coal gasification field trial and modelling experience and refers to the pubic concern and caution by regulators that arise when a commercial or pilot-scale project seeks approval. It will propose solutions for the next generation of underground coal gasification projects. These include the need to access deeper coal seams and the use of new techniques for modelling the process.

scholarly journals Economic Conditions for Developing Hydrogen Production Based on Coal Gasification with Carbon Capture and Storage in Poland

Energies ◽  
2020 ◽  
Vol 13 (19) ◽  
pp. 5074
Author(s):  
Radosław Kaplan ◽  
Michał Kopacz
Keyword(s):  
Carbon Capture ◽  
Coal Gasification ◽  
Net Present Value ◽  
Carbon Capture And Storage ◽  
Economic Assessment ◽  
Free Cash Flow ◽  
Sensitivity Analyses ◽  
Capital Expenditures ◽  
Hard Coal ◽  
And Storage

This study documents the results of economic assessment concerning four variants of coal gasification to hydrogen in a shell reactor. That assessment has been made using discounting methods (NPV: net present value, IRR: internal rate of return), as well as indicators based on a free cash flow to firm (FCFF) approach. Additionally, sensitivity analysis has been carried out, along with scenario analysis in current market conditions concerning prices of hard coal, lignite, hydrogen and CO2 allowances, as well as capital expenditures and costs related to carbon capture and storage (CCS) systems. Based on NPV results, a negative economic assessment has been obtained for all the analyzed variants varying within the range of EUR −903 to −142 million, although the variants based on hard coal achieved a positive IRR (5.1–5.7%) but lower than the assumed discount rates. In Polish conditions, the gasification of lignite seems to be unprofitable, in the assumed scale of total investment outlays and the current price of coal feedstock. The sensitivity analyses indicate that at least a 20% increase of hydrogen price would be required, or a similar reduction of capital expenditures (CAPEX) and costs of operation, for the best variant to make NPV positive. Analyses have also indicated that on the economic basis, only the prices of CO2 allowances exceeding EUR 40/Mg (EUR 52/Mg for lignite) would generate savings due to the availability of CCS systems.

scholarly journals Implementation of Indonesia coal downstream policy in the trend of fossil energy transition

2021 ◽  
Vol 882 (1) ◽  
pp. 012083
Author(s):  
C M Yasin ◽  
B Yunianto ◽  
S Sugiarti ◽  
G K Hudaya
Keyword(s):  
Carbon Capture ◽  
Coal Gasification ◽  
Carbon Capture And Storage ◽  
Value Added ◽  
Energy Transition ◽  
Coal Slurry ◽  
Domestic Use ◽  
The Government ◽  
Environmental Feasibility ◽  
And Storage

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.

scholarly journals Synthesis Gas Composition Prediction for Underground Coal Gasification Using a Thermochemical Equilibrium Modeling Approach

Energies ◽  
2020 ◽  
Vol 13 (5) ◽  
pp. 1171 ◽  
Author(s):  
Christopher Otto ◽  
Thomas Kempka
Keyword(s):  
Synthesis Gas ◽  
Equilibrium Model ◽  
Carbon Capture ◽  
Coal Gasification ◽  
Carbon Capture And Storage ◽  
Equilibrium Composition ◽  
Operating Conditions ◽  
Underground Coal Gasification ◽  
Modeling Approach ◽  
Wide Range

Underground coal gasification (UCG) is an in situ conversion technique that enables the production of high-calorific synthesis gas from resources that are economically not minable by conventional methods. A broad range of end-use options is available for the synthesis gas, including fuels and chemical feedstock production. Furthermore, UCG also offers a high potential for integration with Carbon Capture and Storage (CCS) to mitigate greenhouse gas emissions. In the present study, a stoichiometric equilibrium model, based on minimization of the Gibbs function has been used to estimate the equilibrium composition of the synthesis gas. Thereto, we further developed and applied a proven thermodynamic equilibrium model to simulate the relevant thermochemical coal conversion processes (pyrolysis and gasification). Our modeling approach has been validated against thermodynamic models, laboratory gasification experiments and UCG field trial data reported in the literature. The synthesis gas compositions have been found to be in good agreement under a wide range of different operating conditions. Consequently, the presented modeling approach enables an efficient quantification of synthesis gas quality resulting from UCG, considering varying coal and oxidizer compositions at deposit-specific pressures and temperatures.

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