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Search indexed NASA NTRS and DOE OSTI research on propulsion, heat transfer, battery materials and energy systems. Follow report and document links to the original sources.
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The operations of the NETL baseline Subcritical Pulverized Coal (SubCPC) power plants with or without carbon capture and sequestration (CCS) on the basis of 1 MWh electricity output. To access the model referenced in the report, please visit https://www.netl.doe.gov/energy-analysis/details?id=726C064C-F978-49EB-931C-5F69AD92BD5C
Feedstocks, products, and CO2 emissions for operation of a coal and biomass to liquids plant from report Strategies for Production of Alternative Jet Fuel in the Ohio River Valley. To access the model referenced in the report, please visit https://www.netl.doe.gov/energy-analysis/details?id=EDC49FC1-E81B-41CD-BDE5-069A69F31FEF
Material input for the construction of the NETL baseline supercritical pulverized coal (SCPC) plant with or without carbon capture and sequestration (CCS). To access the model referenced in the report, please visit https://www.netl.doe.gov/energy-analysis/details?id=404A3685-9CEF-4095-91EB-44CCF08D24F4
The amount of steel used in the construction of one shuttle car to be used to haul coal from the working mine face to the conveyor belt in underground mining. To access the model referenced in the report, please visit https://www.netl.doe.gov/energy-analysis/details?id=551741C7-6DA8-4A7A-822B-0991D7FEDC79
Coal integrated gasification solid oxide fuel cell (SOFC) and natural gas (NG) solid fuel cell power plants with and without carbon capture. To access the model referenced in the report, please visit https://www.netl.doe.gov/energy-analysis/details?id=85E9192F-26A2-4A05-914B-9AB64C68538D
The Energy and non-combustion emissions for the operation of a surface coal mine. To access the model referenced in the report, please visit https://www.netl.doe.gov/energy-analysis/details?id=F690F334-2C4A-4C44-BB8C-1D7A080EC94B
Coal-to-liquids (CTL) synthesis using Illinois No. 6 coal via dedicated Fischer-Tropsch facilities or with (F-T) integration with an Integrated Gasification Combined Cycle power plant. To access the model referenced in the report, please visit https://www.netl.doe.gov/energy-analysis/details?id=1BA4D60E-CEF1-4AE3-9CE2-B6C5D6D1CEDF
The amount of electricity required to ventilate an underground coal mine. To access the model referenced in the report, please visit https://www.netl.doe.gov/energy-analysis/details?id=1C16842F-D22F-4C79-B4A4-5423557721F3
The amount of electricity required to power equipment used for cleaning coal at underground and surface mines as well as accounting for coal loss during production activities. To access the model referenced in the report, please visit https://www.netl.doe.gov/energy-analysis/details?id=331FDD97-44BC-41E6-9A95-1E7ECB935098
The need for cleaner energy systems, including CO 2 capture technologies, is driving the current development of chemical looping technologies such as chemical looping combustion (CLC) and chemical looping gasification (CLG). Specific processes that are under development for using solid fuels are in-situ Gasification Chemical-Looping Combustion (iG-CLC) and Chemical Looping with Oxygen Uncoupling (CLOU). Chemical looping is based on using oxygen carriers (e.g., iron oxides, copper oxides, calcium sulfates, etc.) to provide the oxygen for the reaction with the fuel. In order to optimize the overall process performance, it is critical that the properties of the oxygen carriers are well-defined and maintained for their specific purpose during the different stages of the CLC process. One of the critical properties of the oxygen carrier is its oxidation state (e.g., content of Fe 2 O 3 vs. Fe 3 O 4 ) as it affects the fundamental operation of the CLC process. Unfortunately, the ability to make on-line measurements of the oxidation state of oxygen carriers is lacking and new sensors need to be developed. The goal of this project was to evaluate the potential of Raman spectroscopy as a sensor for the on-line analysis of the oxidation state of oxygen carrier particles. Oxygen carrier particles (OCPs) of interest include iron oxides, copper oxides, calcium sulfite, and calcium sulfate, with particle sizes typically less than 0.5 mm diameter. The expected operating conditions of the sensor include OCP temperatures in the range of 800 °C to 1000 °C, and pressures of about 10 atm. We evaluated continuous wave (cw), Quasi cw, pulsed, and time-gated Raman spectroscopy at multiple wavelengths (355 nm, 360 nm, 532 nm, 633 nm, 785 nm). Samples included iron oxides, copper oxides, calcium sulfate, and a custom sample provided by NETL for temperatures beyond 1000 °C. Our findings can be summarized as follows: Calcium sulfate can be detected via cw and pulsed 532 nm Raman spectroscopy at temperatures above 1100 °C.; Hematite (Fe 2 O 3 ) Raman spectra can be detected at temperatures of 700 °C via cw 360 nm, 1089 °C with cw 532 nm, 400 °C with cw 633 and 600 °C with cw 785 nm lasers; Magnetite (Fe 3 O 4 ) can be detected via cw 532 nm Raman spectroscopy up to 600 °C; Mixtures of Fe2O3 and Fe 3 O 4 can be distinguished for temperatures up to 600 °C using 532 nm; Copper oxides did not yield suitable signals at elevated temperatures; The custom NETL samples did not yield suitable signals at elevated temperatures. Raman spectroscopy would be a suitable approach for calcium sulfate as this material provides a very strong Raman signal at high temperatures. Oxygen carrier particles of higher interest such as metal oxides, however, do not yield a strong-enough signal at elevated temperatures. As such, Raman spectroscopy is not suitable to differentiate the oxidation state of these materials at temperatures above 600 °C.
The Ohio State University (OSU) coal to syngas (CTS) technology is an advanced air separation process that can be applied for electricity production via an integrated gasification combined cycle (IGCC). The objective of the proposed project is to enable the OSU CLG technology for a commercially relevant demonstration by 2020. In order to accomplish this objective, small pilot scale demonstration of the CLG reactor system was performed. The small pilot test unit incorporates commercially scalable non-mechanical gas sealing and solids flow control components for extended operations of the integrated reactor system. A cumulative demonstration of greater than 100 hours was performed to confirm the reliability of the reactors (reducer and oxidizer) and non-mechanical devices in maintaining controlled solid circulation, gas sealing, and coal distribution in the reactor (reducer) as well as to confirm sustained syngas product performance. A comprehensive techno-economic analysis (TEA) of the OSU CLG process for IGCC application was conducted with the support of WorleyParsons, Ltd. (WP) and compared to the Department of Energy (DOE) baseline IGCC report. Using the data gained from the small pilot demonstration, a complete comprehensive techno-economic analysis (TEA) of the CLG process was conducted. The evaluation was used as basis to attract utilities and coal industries in Ohio. The project duration lasts 30 months (6 months of no cost extension). Ohio coal was used in the integrated CLG small pilot unit to convert to high hydrogen syngas. A demonstration of the integrated chemical looping reactor system at the 15 kW th scale accelerates technology commercialization in the near term. The 15 kWth demonstration addressed several major technology gaps, such as coal injection and distribution in the reducer, controllable solids circulation with the desired fuel to solids ratio, system pressure distribution for proper gas sealing, effects of contaminants and fuel/oxygen carrier residence time requirements. The fates of impurities, such as SO x and NO x was also investigated in unit demonstrations. WP conducted a comprehensive system TEA to optimize the OSU CLG process design for efficient electricity generation with greater than 90% CO 2 capture in IGCC applications. The conclusion of this project supports the further scale-up of the technology to a commercially applicable large pilot scale test unit for operation by 2020. More importantly, it benefits Ohio as it provides an economically competitive mean for power generation with carbon capture. Given the rise of natural gas usage and strict environmental regulations, the use of Ohio coal is expected to decrease and thus impact the coal economy in Ohio. The conclusion of this project provided way for Ohio coal to compete in the future and secure jobs in the energy sector.
Southern Research has developed a combined CO 2 capture water-gas shift (WGS) process for integrated gasification combined cycle (IGCC) applications. A highly efficient regenerable magnesium based sorbent was prepared to remove CO 2 . It offers high and stable CO 2 capacity with minimum requirement for temperature and pressure swings. Under optimized conditions, the sorbents achieved up to 8 mmol/g of CO 2 working capacity and remained stable over 500 cycles of adsorption and regeneration. The selected WGS process achieved 96% CO per pass conversion and remained isothermal during the test duration that lasted over 500 cycles. The approach showed potential to reduce cost of electricity (COE) compared to the baseline carbon capture approaches. The process is for bench-scale and pilot development. In a commercial embodiment, syngas from the gasifier is cooled to warm gas conditions. It then enters the CO 2 sorbent-shift reactor that uses an efficient MgO-based CO 2 sorbent and a commercial catalyst to shift the CO to CO 2 and capture 90% + of the carbon. Using a dual-bed arrangement, the sorbent is regenerated periodically by a combination of pressure and temperature swing to maintain steady state conditions and produce a 95+ % CO 2 stream for sequestration. The hydrogen rich syngas is sent to the IGCC for power production. In addition to consolidating CO 2 capture with WGS, the proposed process reduces parasitic energy losses by operating at warm gas temperatures and reduces parasitic plant load (i.e., steam and auxiliary power) by reducing energy required for regeneration. The project consisted of 3 budget periods (BP) of laboratory-scale research and testing with go/no-go decisions after BP-1 and BP-2. In the 12 month BP-1, it was shown show that one promising sorbent maintained the required CO 2 capacity and durability of >1.5 mmol/g over 100 cycles. Also based on sorbent and WGS experiments in separate reactors and combined reactor modeling, it was shown that the process had the potential to capture 90% of the CO 2 at a lower than conventional amine-based approach. In the 18 month BP-2, a lab scale combined sorbent/WGS reactor system was built, commissioned, and tested with the promising sorbent from BP-1. 90% carbon capture was demonstrated over 100 cycles and it was shown that the process continued to have potential to capture 90% of the carbon at a cost that was less than the conventional amine-based approach. In the 6 month BP-3, a long term test was conducted using the best SR sorbent. The required durability of > 2 mmol/g was demonstrated after 500 cycles. Also, 90% carbon capture and 96% CO conversion was maintained over 1000 cycles. A technical and economic feasibility study was carried out to compare the proposed pre-combustion approach to a gasification plant employing a conventional pre-combustion approach and a conventional pulverized caol (PC) plant employing a conventional post combustion CO 2 capture approach.
This presentation discusses carbon capture retrofit analyses for existing coal and natural gas power plants, and industrial facilities. Also discussed is development of an analysis tool that would quantify the cost and performance impacts of CCS retrofits.
This analysis evaluates CO 2 capture-ready supercritical pulverized coal units. Cost and performance results are presented for capture-ready coal units that achieve a 30-year average emission rate of 1,000 Lb CO 2 /MWh. The analysis also includes a detailed discussion of the specific elements that comprise a capture-ready unit, as well as different design strategies to minimize costs. The benefits of R&D advances such as 2nd generation CO 2 capture, and additional revenue from CO 2 sales for enhanced oil recovery, are also presented, and are compared to other baseload generation options, such as natural gas combined cycle and nuclear.
Coal has been historically the fuel to satisfy the United States’ need for baseload electricity generation. Increasingly stringent environmental regulations (specifically uncertainty for CO 2 emission regulations), are forcing the electric power industry to scrutinize the long-term viability of new and existing coal-fueled assets. The development of advanced, higher efficiency coal power generation technologies leading to reductions in CO 2 and other emissions and competitive costs are one avenue to address these concerns. A goal of this study was initially to identify one or more conceptual designs for a coal-fired power plant that could meet the existing “Carbon Pollution Standard (CPS) for New Power Plants” without dedicated CO 2 capture equipment. Since the EPA proposals are still under the review process, this report uses the current limits. Additional goals include: sCO 2 cycles systems that achievie an efficiency > 46.7 % HHV and a cost of electricity of < $82.3/MWh.
This presentation provides an overview of the coal industry, focusing on the United States, but within a global context. Areas covered include coal prices, consumption, production, imports, exports, reserves, productivity measures, and more. Juxtapositions between the U.S. and other countries' coal industries are provided. In addition to providing a current snapshot of the U.S. coal industry, this work portrays both historical and projected aspects of the coal industry.
This report provides an overview of the coal industry, focusing on the United States. Some of the areas covered include coal prices, consumption, production, stockpiles, imports, exports, reserves, and productivity measures. Juxtapositions between the United States and other countries' coal industries are provided. In addition to providing a current snapshot of the U.S. coal industry, this work portrays both historical and projected aspects of the coal industry.
This report establishes performance and cost data for coal-to-liquids systems, specifically by means of gasification and Fischer-Tropsch reaction. The analyses were performed on a consistent technical and economic basis to assess the design and financial performance of a commercial-scale coal-to-Fischer-Tropsch liquids facility. The cost and performance data were compiled from published reports, information obtained from vendor quotes and users of the technology, and data from designing and building utility and refining projects.