SEARCH · Search NASA

Results for “FOSSIL”

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.

SourceResearch connectionFrom yearThrough year

Quote a phrase for an exact phrase match. Source license links do not imply unrestricted reuse.

At least 1,513 records · Page 84

All sources NASA NTRS DOE OSTI

DOE OSTI2016

Operating experience of a 50kWth methane chemical looping reactor

Chemical Looping Combustion (CLC) has the potential to efficiently capture CO2 from the combustion of fossil fuels at an affordable price. CLC is a process that produces a flue gas primarily consisting of CO2 and H2O. The CO2 can be easily separated and captured by condensing the H2O, similar to an oxy-fuel process. Although the process looks promising on paper, the challenge of making chemical looping a reality involves demonstrating that the process is technically feasible. To help achieve this goal, the U.S. Department of Energy’s (DOE) National Energy Technology Laboratory (NETL), has constructed and tested a 50kWth chemical looping reactor (CLR). The general arrangement of the process consists of a bubbling fluidized bed fuel reactor and a fluidized bed/riser air reactor. This paper will describe the results from a hematite ore that has been tested during a week-long test campaign.

01 COAL, LIGNITE, AND PEAT↗

DOE OSTI2018

Techno-Economic Analysis and Life-Cycle Assessment for Gas Phase Catalytic Oxidation of Lignin to Produce Phenolic Compounds

Displacing fossil fuels with biofuels is an effective way to sustainably mitigate greenhouse gas (GHG) emissions and natural resource consumption. As DOE's only national laboratory solely dedicated to researching and developing clean energy and energy efficiency technologies, NREL has been developing conceptual biomass-to-fuels conversion processes. To improve the economic feasibility of biofuels production from lignocellulosic biomass, NREL's researchers have been exploring various design options. Our team has developed a vapor phase selective oxidation process that will convert lignin streams from biofuels production into high-value chemicals and thereby improve the economics and GHG emissions of biofuels plants. This approach is directed towards valorizing lignin, which is often treated as waste or burnt for low value process heat. For techno-economic analysis (TEA) and life-cycle assessment (LCA), we have developed and modeled this hybrid process: 1) biochemically converting C5/C6 sugars from biomass to a hydrocarbon blendstock, and 2) thermochemically converting lignin from biomass, via selective partial oxidation of lignin pyrolysis vapor, to phenols. Results from the TEA and LCA for this process will be presented and discussed. The lignin valorization readily improves the biofuel production cost and reduces the life cycle carbon footprint. Even though more electricity is required as lignin is used for coproduct production instead of for heat and power generation, the GHG coproduct credit from phenols is more than enough to compensate for the GHG associated with the additional import electricity use. These analyses show that our process to produce phenol has significant economic and environmental impacts, which will enable biofuel production.

09 BIOMASS FUELS↗

DOE OSTI2019

SUBTASK 2.3 – SUPPORT OF DOE CARBON CAPTURE SYSTEMS DEVELOPMENT AND MODELING

The ultimate goal of this project is to reduce uncertainty in the deployment of carbon capture and storage (CCS) technologies by overcoming key challenges through a combination of experimentation and modeling studies. The studies focused on key areas of concern for CCS systems and worked to increase overall confidence in the technology. To achieve project goals, the Energy & Environmental Research Center (EERC) identified the following objectives: Determine the potential impacts of coal combustion-derived aerosols on solvent emissions, solvent degradation, and fouling of postcombustion CO2 capture systems. Identify methods to control the formation of aerosols. Evaluate, quantify, and document the regional impacts that could result from implementation of CO2 capture technologies and enhanced oil recovery. Support U.S. Department of Energy (DOE) modeling efforts by providing key information to help reduce the uncertainty of future CCS projects and increase investor and public confidence in the technologies. Four activities were executed to support this effort, and the detailed results of these activities are presented herein. This project was cofunded through the EERC–DOE Joint Program on Research and Development for Fossil Energy-Related Resources Cooperative Agreement No. DE-FE0024233. Nonfederal funding was provided by the North Dakota Industrial Commission, Mitsubishi Heavy Industries America, Minnkota Power Cooperative, ALLETE, and the Lignite Energy Council.

01 COAL, LIGNITE, AND PEAT↗

DOE OSTI2019

Subtask 2.5 – Syngas Testing of NETL's Advanced Precombustion CO2 Capture Solvent

U.S. Department of Energy (DOE) National Energy Technology Laboratory (NETL) on-site researchers have been examining and developing a novel solvent for precombustion capture that has the potential for improved performance and lower costs compared to Selexol™ and Rectisol®. In Subtask 2.5, the Energy & Environmental Research Center (EERC) conducted actual comparison tests on actual coal-derived syngas of a PEGDME (polyethylene glycol dimethyl ether) Selexol-type solvent and three other solvents provided by NETL. One was a new hybrid PEG–PDMS (poly[dimethylsiloxane]) solvent engineered by NETL. In addition, two commercially available chemicals that are projected to have good CO2 capture abilities were also selected for testing on actual coal-derived syngas. These tests were conducted in the EERC high-pressure fluid-bed gasifier (HPFBG) system utilizing an existing gas-sweetening absorption system (GSAS) to test the solvents. The four solvents tested were Solvent 1 – AGR II from Coastal Chemical Co., LLC, NETL Solvent 2 – XG-3229 Bis(methoxytriethyleneoxypropyl)hexamethyltrisiloxane, as manufactured by Gelast, Inc.; Solvent 3 – CASSH-1 (diethyl sebacate), procured from Sigma Aldrich; and Solvent 4 – TBP (tributyl phosphate), purchased from ThermoFisher Scientific. The solvents were all tested at a consistent syngas flow and composition at approximately 50 bar to make direct comparisons easier; two solvent flow rates which would bracket 90% CO2 capture; and, temperatures of 10°, 25°, 40°, and 55°C to determine the effects of temperature on CO2 uptake and CO2 to H2 selectivity. Figure E-1 shows the results for CO2 uptake and selectivity for the various solvents. These data show that the CO2 uptake for the Selexol-type solvent for the PEG-PDMS-3 and CASHH-1 solvents at higher operating temperatures around 40°C was better than the Selexol-type solvent was able to achieve at the lower operating temperature of 10°C. Selectivity of CO2 over H2 was at least as good as Selexol for the PEG-PDMS-3 solvent and even better than Selexol for the CASSH-1 solvent. The TBP solvent also displayed good CO2 uptake; however, CO2/H2 selectivity was worse than for the Selexol-type solvent. Operation of precombustion CO2 solvents at temperatures above ambient can provide a 2% process efficiency improvement along with a significant capital cost reduction since refrigeration and solvent dehydration equipment is not required. The excellent results from these tests warrant further longer-duration testing with one or both superior NETL-provided solvents to determine if longer-term exposure to any coal-derived syngas trace species may have an adverse impact on solvent performance. This project was funded through the EERC–DOE Joint Program on Research and Development for Fossil Energy-Related Resources Cooperative Agreement No. DE-FE0024233.

01 COAL, LIGNITE, AND PEAT↗

DOE OSTI2019

Developing CO 2 Source and Storage Opportunities across the Illinois Basin Subtask 5.3 – Regional Roadmap for Source Network and Storage Deployment Topical Report

Large-scale anthropogenic CO 2 sources (>100,000 tonnes/year) were catalogued for the CarbonSAFE Illinois East Sub-Basin carbon capture and storage pre-feasibility study. The source portfolio is diverse, consisting of fossil-base power production, ethanol production operations, chemical development, and refinery facilities, most of which are relatively new or modernized (i.e. post year 2000). Ten facilities were considered for potential commercial-scale geological storage in a regional CO 2 source and storage network study. The study area has a number of potential geologic sequestration targets, including three significant deep saline reservoirs with corresponding seals, and potential enhanced oil recovery (EOR) opportunities. Recent research has focused on a high-porosity, highly arkosic zone within the Lower Mt. Simon Sandstone. Based on this work, we present a conceptual CO 2 source and storage network, which focuses on the arkosic zone in the Lower Mt. Simon as a prospective storage resource play in the Illinois East Sub-Basin region.

01 COAL, LIGNITE, AND PEAT↗

DOE OSTI2019

"250 kWt Pilot Testing in Support of a 10 MWe Coal-Direct Chemical Looping Demonstration Feasibility Study

The Babcock & Wilcox Company and The Ohio State University are developing iron-based metal oxide chemical looping technology for power generation and conversion of fossil fuels to chemicals and liquid fuels. A 250 kWt pilot facility has been constructed at the Babcock & Wilcox Research Center in Barberton, Ohio. Testing was conducted on the facility to support scale-up of the technology for implementation in a 10 MWe coal direct chemical looping large pilot plant at Dover Light & Power in Dover, Ohio. The paper discusses the results of the pilot test and the impact of the results on the design of the large pilot facility.

20 FOSSIL-FUELED POWER PLANTS↗

DOE OSTI2019

Solid Oxide Fuel Cell Gas Turbine Hybrids for Distributed Generation

Given the need for clean and reliable energy, fuel cell technologies offer the ability to produce extremely low-emission electricity from reliable fossil energy. A standalone solid oxide fuel cell (SOFC) module can reach electrical efficiencies of about 60%. However, coupling a SOFC to a Brayton style gas turbine (GT) increases the efficiency of the system to 70-75% or more. Using results from NETL’s HYPER Lab and published research, this project evaluates the strengths, limitations, and potential applications of SOFC-GT hybrids.

03 NATURAL GAS↗

DOE OSTI2020

Update on the United States Advanced Ultra-Supercritical Program with Full Scale Component Fabrication to Develop Utility Scale Power Plants with 760°C Steam Temperature

Following the successful completion of a 15-year effort to develop and test materials that would allow coal-fired power plants to be operated at advanced ultra-supercritical (A-USC) steam conditions, a United States-based consortium is presently engaged in Phase 2 of a project which includes an advanced manufacturing effort to complete US-based supply chain development for full commercial scale (800-850 MWe) A-USC components made of nickel-based alloys, components operating at up to 760°C. The project, funded under U.S. Department of Energy Award No. DE-FE0025064, falls under the US DOE overall goal to Develop cost-effective, reliable technologies to improve the efficiency of new and existing coal-fired power plants. A-USC steam cycles have the potential to improve cycle efficiency, reduce fuel costs, and reduce greenhouse gas emissions. Current development and demonstration efforts are focused on enabling the construction of A-USC plants, operating with steam temperatures as high as 1400°F (760°C) and steam pressures up to 5000 psi (35 MPa), which can potentially increase cycle efficiencies to 47% HHV (higher heating value), or approximately 50% LHV (lower heating value), and reduce CO 2 emissions by roughly 25%, compared to today’s U.S. fleet. A-USC technology provides a lower-cost method to reduce CO 2 emissions, compared to CO 2 capture technologies, while retaining a viable coal option for owners of coal generation assets. Among the specific goals of Phase 2 of the ComTest Project are to: validate that components made from advanced nickel-based alloys can operate and perform under A-USC conditions accelerate the development of a U.S.-based supply chain for the full complement of A-USC components close the remaining gaps and reduce the risks for manufacturing components from advanced materials for commercial demonstration fabricate full-scale versions of selected key components made of nickel-based alloys validate a qualified U.S. supply chain, to provide greater cost certainty for components obtain American Society of Mechanical Engineers (ASME) code approval for new materials, components and processes Additional benefit: Manufacturing technology will be applicable to other advanced fossil energy high temperature cycles, and can support increased flexibility of existing power plants The ComTest project is managed by Energy Industries of Ohio, and technically directed by the Electric Power Research Institute, Inc., with General Electric designing the A-USC components. As stated earlier, the current phase of the effort is primarily funded by the U.S. Department of Energy, through the National Energy Technology Laboratory. This presentation outlines the motivation for the project, explains the project’s structure and schedule, and provides some of the technical details on the design of the ComTest components.

01 COAL, LIGNITE, AND PEAT↗

DOE OSTI2020

Update on the United States Advanced Ultra-Supercritical Program with Full Scale Component Fabrication to Develop Utility Scale Power Plants with 760°C Steam Temperature

01 COAL, LIGNITE, AND PEAT↗

DOE OSTI2020

Hybrid Analytics Solution for Power Plant Operations

Expert Microsystems, Inc., MapEx Software Inc. and XMPLR Energy LLC have teamed to submit a proposal to the US Department of Energy’s Office of Fossil Energy to improve the efficiency, reliability and flexibility of existing coal-based power plants. The project, titled Hybrid Analytics Solution to Improve Coal Power Plant Operations (the “Hybrid Analytics” project), will develop, demonstrate and commercialize a novel approach that integrates two proven real-time monitoring techniques. The Hybrid Analytics approach integrates into a single, integrated solution: a) an established, advanced data-driven analytics solution that includes artificial intelligence, advanced pattern recognition and machine-learning techniques and b) a well-proven, first principle thermal heat balance model solution. The future role of coal plants will depend on the ability to cycle and follow loads to meet marginal power demands, accommodate renewables and support the grid. Essential to success in this new role is a plant’s ability to maintain high reliability, efficiency and flexibility. However, these changing operational demands put significant stresses on power plant components that directly impact the ability to deliver these requirements. In the past, plants have independently monitored performance using physics-based solutions (heat rate, boiler losses, etc.) and reliability using data-driven analytics (advanced pattern recognition). The Hybrid Analytics solution integrates both approaches to enhance fault detection, provide automated diagnostics and estimates of remaining time to act, and provide critical, enhanced and accurate real-time information to coal plant operators. As a result, coal plants can improve efficiency, reliability, and flexibility and can cost-effectively maintain their key role in the power delivery system.

01 COAL, LIGNITE, AND PEAT↗

DOE OSTI2021

Analysis of Various Polysulfone-nanodiamond Mixed-Matrix Membranes

Historically, coal combustion systems have contributed to the extensive network of energy production across the world. Oxycombustion has been shown to be more energy efficient and can facilitate carbon capture from fossil energy utilization. The challenge for small modular deployment of coal combustion or gasification systems is that current O2 enrichment technologies do not scale downward cost-effectively. Fortunately, membrane processes have been developed to offer a more viable polymer-based technology for this application. The central focus is to deliver a high-performance polymer membrane capable of enriching O2 to 90-95% in oxycombustion systems for small modular coal-based power or gasification plants. To accomplish this, various properties of polysulfone-nanodiamond mixed-matrix membrane are examined to determine the appropriate conditions for applicable use. The polymers are infused with nanoparticles to increase the mechanical functionality of the structure which in turn alters the permeability and selectivity of the membrane. Furthermore, the thermal history can also impact the functionality and characteristics of these polymer systems. This study primarily discusses the structure and function of these assorted membranes in terms of permeability and thermomechanical characteristics.

01 COAL, LIGNITE, AND PEAT↗

DOE OSTI2022

sCO2 Primary Power Large-Scale Pilot Plant FEED Summary

Echogen Power Systems and its project partners the Electric Power Research Institute, CDM Smith, Riley Power Inc. (a Babcock Power Inc. company), and the University of Missouri completed the Front-End Engineering Design (FEED) study of a nominal 10 MWe supercritical carbon dioxide (sCO2) large-scale pilot plant based on Recompression Brayton Cycle (RCBC) architecture. The FEED study was completed under Phase II of the U.S. Department of Energy Fossil Fuel Large-Scale Pilots program. The FEED study scope included the preliminary design of the combustion and environmental control systems, the primary heater, the sCO2 power cycle and its associated turbomachinery, and the balance of plant equipment to determine accurate cost and schedule requirements for fabrication and installation of the system at the University of Missouri’s Combined Cooling, Heat, and Power Plant, located in Columbia, Missouri. The RCBC sCO2 cycle presents superior thermodynamic efficiency compared to steam-Rankine cycles and is adaptable to a broad range of heat sources. The risk aversion of the power generation industry requires a successful large-scale pilot plant demonstration to enable financing and deployment of commercial-scale plants. Therefore, successful construction and demonstration of a 10 MWe RCBC sCO2 power plant would empower a transformational step forward for the efficiency of the next generation of utility power plants. This paper provides details on the primary heater, environmental control systems, and sCO2 power cycle design and performance.

01 COAL, LIGNITE, AND PEAT↗

DOE OSTI2022

It's Not Just About the Megawatts - ARC Industry Forum, The Future of Power Generation

As the world transitions to less carbon intensive energy portfolios, much of the attention understandably centers on generating capacity – replacing megawatts of fossil fuel with megawatts of solar, wind, nuclear, hydroelectric, hydrogen, and more. The actual operation of a reliable grid needs more than just megawatts though: adequate quantities of a portfolio of essential reliability services; flexible and capable power delivery systems; governance to operate in 5-10 minute intervals, forecast hourly, and plan and build on a generational time horizon; and dependable and secure communications. We can choose our fuel mix for climate reasons, but the grid itself and the society that relies upon it impose constraints on those choices that we ignore at our peril.

13 HYDRO ENERGY↗

DOE OSTI2011

The Energy Future - The Have's and the Have Not's (What can Jared Diamond tell us about the future of our wonderful little discovery?)

This presentation explains in a huge series of slides why nuclear power will necessarily be part of the sustainable, safe, CO{sub 2}-free, environmentally-friendly, job creating, economic and human energy future. It stresses on the strong environmental impacts and hazardous aspects of fossil fuels and of some renewable energy sources as well like wind- and hydro-power.

22 GENERAL STUDIES OF NUCLEAR REACTORS↗

DOE OSTI2012

Gaseous fission product management for molten salt reactors and vented fuel systems

Fission gas disposal is one of the unresolved difficulties for Molten Salt Reactors (MSRs) and advanced reactors with vented fuel systems. As these systems operate, they produce many radioactive isotopes of xenon and krypton (e.g. {sup 135}Xe t{sub 1/2} = 9.14 hours and {sup 85}Kr t{sub 1/2}= 10.73 years). Removing these gases proves vital to the success of such reactor designs for two reasons. First, the gases act as large neutron sinks which decrease reactivity and must be counterbalanced by increasing fuel loading. Second, for MSRs, inert fission product gases naturally separate quickly from high temperature salts, thus creating high vapor pressure which poses safety concerns. For advanced reactors with solid vented fuel, the gases are allowed to escape into an off-gas system and thus must be managed. Because of time delays in transport of fission product gases in vented fuel systems, some of the shorter-lived radionuclides will decay away thereby reducing the fission gas source term relative to an MSR. To calculate the fission gas source term of a typical molten salt reactor, we modeled a 1000 MWe graphite moderated thorium MSR similar to that detailed in Mathieu et al. [1]. The fuel salt used in these calculations was LiF (78 mole percent) - (HN)F 4 (22 mole percent) with a heavy nuclide composition of 3.86% {sup 233}U and 96.14% {sup 232}Th by mass. Before we can remove the fission product gases produced by this reactor configuration, we must first develop an appropriate storage mechanism. The gases could be stored in pressurized containers but then one must be concerned about bottle failure. Methods to trap noble gases in matrices are expensive and complex. Alternatively, there are direct storage/disposal options: direct injection into the Earth or injecting a grout-based product into the Earth. Advances in drilling technologies, hydro fracture technologies, and methods for the sequestration of carbon dioxide from fossil fuel plants are creating new options for disposal of fission gas wastes. In each option, lithostatic pressure, a kilometer or more underground, eliminates the pressure driving force for noble gas release and dissolves any untrapped gas in deep groundwater or into incorporated solid waste forms. The options, challenges, and potential for these methods to dispose of gaseous fission products are described. With this research, we hope to help both MSRs and other advanced reactors come one step closer to commercialization. (authors)

21 SPECIFIC NUCLEAR REACTORS AND ASSOCIATED PLANTS↗

DOE OSTI2016

Conceptual System Design of a Supercritical CO{sub 2} cooled Micro Modular Reactor - 18492

Small modular reactor (SMR) concepts proposed in the past have compact size and a longer life reactor core than the conventional nuclear power plants. However, previous concepts based on the water-cooled technologies with a steam Rankine cycle have shown that the complete modularization is still technically challenging. This study suggests an innovative concept of a reactor directly cooled by supercritical carbon dioxide (S-CO{sub 2}) with S-CO{sub 2} Brayton cycle as a power conversion system, namely KAIST MMR (Micro Modular Reactor). To enhance neutron economy and maximize the fuel volume fraction of the core, a uranium carbide fuel controlled by drum type control rods was used in the fast-spectrum MMR. The core has long life (20 years) without refueling or reshuffling as well as inherent safety features. The reactor can be used as a distributed power source, and replace outdated fossil fuel power plants for small cities. Moreover, we propose a S-CO{sub 2} Brayton cycle as a power conversion system to achieve small, high performance and lightweight module. Thanks to the compact core and power conversion system, the entire system can be contained in a single module. The target of the system is to achieve small and compact system that can be transported via ground transportation of a single module containing the core and the power conversion system altogether. In order to meet this target single module s total weight is minimized in the order of 150 tons. The external size of a module is less than 7 m in length and 4 m in diameter. It produces 12 MWe electricity from 36 MWt reactor core. The S-CO{sub 2} Brayton cycle was optimized, and the cycle components were designed while maximizing the performance and minimizing the weight. A passive decay heat removal system utilizing shell and tube heat exchangers was also developed, and examined its performance with transient analysis code. (authors)

21 SPECIFIC NUCLEAR REACTORS AND ASSOCIATED PLANTS↗

DOE OSTI2016

Synthesis and Adsorption Studies of a Novel Bifunctional Uranium Chelator

With catastrophic effects of climate change already being experienced around the world, there is an ever-growing need to transition away from fossil fuel-centric energy production to means that are more environmentally conscious. Since nuclear energy is the only mature, scalable technology that is capable of large-scale energy production with negligible environmental externalities, there has been much interest in securing a stable supply of uranium to meet worldwide nuclear energy demand. The amount of uranium in conventional deposits, however, is limited to only 100 years if used at current consumption rates. Containing well over 4.5 billion tons of uranium, earth's oceans represent a nearly infinite supply. The work described herein is concerned with the front-end of the nuclear fuel cycle; that is, the development of strategies for accumulating raw uranium feedstock from the ocean for further enrichment and refining. The objective of this work is to design, synthesize, and characterize a bifunctional chelating ligand containing a carboxylic acid and an amidoxime functionality orientated for optimal uranyl binding. (authors)

11 NUCLEAR FUEL CYCLE AND FUEL MATERIALS↗

DOE OSTI2017

Nuclear Fuel Cycle Simulator as a Means to Model a Nuclear Hybrid Energy System

With a growing concern for how greenhouse gas (GHG) emissions impact climate change, there is a clear value in minimizing reliance on fossil fuels. Fluctuating renewable energy sources continue to penetrate the grid at higher levels. One means of ensuring a reliable electricity supply, while maintaining low overall GHG emissions, is to couple a nuclear power plant to the fluctuating renewable electricity source. Nuclear hybrid energy systems (NHES) focus on combining renewable and nuclear generation with industrial processes to ensure reliable energy generation as well as profitability of the system as a whole. This paper analyzes the current state of NHES models, and suggests how a nuclear fuel cycle simulator (NFCS) could be used to quickly model a nuclear hybrid energy system to address long term policy concerns. NFCSs are used to model the nuclear fuel cycle, which consists of uranium mining, enrichment, the reactor, reprocessing, and long term storage of waste. The simulations can span over hundreds of years to demonstrate different approaches to managing costs, waste disposal, and proliferation concerns. Current NHES models, on the other hand, focus on shorter time periods, primarily on a daily to weekly scale, and answer questions surrounding feasibility and costs for both normal and extreme scenarios. First, this paper will discuss the different criterion that are important to modeling a NHES. Then, we will break down the characteristics of a NFCS, analyzing how the characteristics of NHES and the fuel cycle overlap. After discussing the current modeling approaches for NHES and NFCS, this paper will analyze the benefits of using a NFCS to model a NHES. This paper will conclude that a NFCS, if appropriately augmented to account for the dynamic aspects of a NHES, can produce a flexible, high level NHES model quickly.

11 NUCLEAR FUEL CYCLE AND FUEL MATERIALS↗