The FutureGen Industrial Alliance, Inc. (Alliance) will perform this component of FutureGen 2.0, involving pipeline transportation of CO2 from Ameren's Meredosia plant to a geologic storage reservoir. The project will require selection by the Alliance of a reservoir site through a competitive process. It will also require, in part, evaluation and selection of pipeline routes and supplemental compression (if necessary); development of visitor and education facilities; and pipeline and storage construction and operations.

HECA will design, build and operate a greenfield, commercial scale, advanced Integrated Gasification Combined Cycle (IGCC) power plant and fertilizer production facility with CO2 capture in Kern County, California. The HECA Project is designed to achieve at least 90% CO2 capture efficiency while storing approximately 2.6 million tons per year in an enhanced oil recovery (EOR) application. The captured CO2 will be transported via pipeline to the Elk Hills oil field approximately 4 miles from the power plant. The project will employ IGCC technology to nominally generate 400 megawatts electrical (MWe) (gross) and up to 300 MWe (net) of electricity and produce approximately 1 million tons per year of fertilizer using a 75% coal/25% petroleum coke fuel blend. The fertilizer could be a combination of urea ammonium nitrate, urea, or other fertilizer equivalent, with the proportion dependent on market and commercial conditions.

The objective of this Project is to develop technologies under realistic conditions that will reduce the cost of advanced coal-fueled power plants with CO2 capture. This technology development will include the design, procurement, construction, installation, and operation of a flexible facility for the testing of processes for pre-combustion CO2 capture, post-combustion CO2 capture and oxy-combustion. Components and systems that are appropriate for inclusion in the detailed test plan will be identified in collaboration with NETL. In addition to evaluating DOE sponsored projects, projects from industry, universities, and EPRI will be evaluated to assist in accomplishing the Project objectives.

The project is to develop via laboratory-based experiments an advanced pressure swing absorption-based device. This accomplishes a cyclic process that will produce purified hydrogen at a high pressure for IGCC-CCS plant's combustion turbine from low temperature post-shift reactor synthesis gas. Simultaneously, this separation process obtains a highly purified CO2 stream containing at least 90% of the CO2 in the post-shift reactor gas stream which is suitable for subsequent sequestration steps. This cyclic or batch process is achieved without a membrane or extensive plumbing required for continuous flow. An objective of this project is to provide data and analysis so that scale-up is facilitated during subsequent design and scale-up.

The goal of this project is to investigate and explore the applicability of Pulsed Laser Deposition (PLD) technique as an activation step followed by surfactant induced electroless deposition as novel route to fabricate hydrogen-selective Pd/Pd-alloy composite membrane on microporous substrate for use in production and separation of hydrogen at elevated temperature and pressure.

The overall goal of this project is the development of solid oxide fuel cell (SOFC) cell and stack technology suitable for use in highly-efficient economically-competitive central generation power plant facilities fueled by coal synthesis gas (syngas).

The overall objective of this project is to understand the role of cathode surface properties on Solid Oxide Fuel Cell (SOFC) performance. SOFC cathodes are responsible for the particularly difficult reaction whereby oxygen from the air in a fuel cell is converted into an ion which then migrates across a solid membrane to then react with fuel to form water or CO2. In this project, the surface properties of some catalytic cathode materials will be characterized with a variety of advanced analytical techniques and the results will be compared with the known reactivity of these materials to understand how and why some materials work better than others as SOFC cathodes. It is expected that this understanding will guide future cathode development such that SOFC-based power generation systems become more efficient and cost-effective.

The overall objective of this project is to understand the role of cathode surface properties on Solid Oxide Fuel Cell (SOFC) performance. SOFC cathodes are responsible for the particularly difficult reaction whereby oxygen from the air in a fuel cell is converted into an ion which then migrates across a solid membrane to then react with fuel to form water or CO2. In this project, the surface properties of some catalytic cathode materials will be characterized by CMU with a variety of advanced analytical techniques and the results will be compared with the known reactivity of these materials to understand how and why some materials work better than others as SOFC cathodes.

This 5-year Innovative Concepts project will focus on the investigation of solid oxide fuel cell (SOFC) degradation mechanisms and the development and implementation of effective mitigation strategies. It builds upon the work performed at the end of a prior GE cooperative agreement DE-FC26-05NT42614, originally a SECA Industry Team project. In January 2007 the GE Industry Team project was substantially de-scoped at GE's request. GE closed its Hybrid Power Generation Systems facility located in Torrance CA and reduced the scope of the effort to focus on fundamental cell research and development issues - primarily power density enhancement and materials stability (degradation). In September 2009 the cooperative agreement was slightly refocused to emphasize alternative cell manufacturing techniques and de-emphasize chromium barrier coating development.

The goal of this project is to acquire experimental data required to assess the feasibility of a Direct Coal power plant based upon a Liquid Tin Anode Solid Oxide Fuel Cell (LTA-SOFC).

Research will investigate and characterize nano-scale variations and modifications of the solid oxide fuel cell (SOFC) cathode/electrolyte interface region. These modifications will be correlated to the effects of current, gaseous environment, and possible synergistic effects between them. Correlations will be established between the operating conditions, the degradation, and the observed chemical or structural modifications that are fundamentally responsible for the degradation. Once identified, methods to mitigate or prevent degradation can be proposed and investigated.

The overall objective of this project with the Massachusetts Institute of Technology (MIT) is to understand the role of cathode surface properties in Solid Oxide Fuel Cell (SOFC) performance. In this project, the surface properties of some catalytic cathode materials will be characterized with a variety of advanced analytical techniques and the results will be compared with the known reactivity of these materials to understand how and why some materials work better than others as SOFC cathodes and to inspire the generation of new materials with even better performance.

The objectives of this Pennsylvania State University (Penn State) and Delphi project are to develop new fuel processing approaches for using select alternative and renewable fuels - commercial diesel fuel and anaerobic digester gas (ADG) - in solid oxide fuel cell (SOFC) power generation systems, and to conduct integrated fuel processor-SOFC system tests to evaluate the performance of the fuel processors and overall systems.

The Arrowhead Center to Promote Prosperity and Public Welfare (PROSPER) of the New Mexico State University (NMSU) is conducting research analyzing the relationships between the fossil fuel energy sector and economic development issues in New Mexico. The project is a policy research and economic modeling initiative to enhance fossil fuel energy production and use in New Mexico in an environmentally progressive manner that contributes to the economic development of the state and creates a strong, vibrant economy that better serves the citizens of New Mexico. The project is engaging stakeholders in the research process and assessing (1) the impact of the fossil fuel industry on water resources in New Mexico, and (2) how the increasing worldwide demand for fossil fuels impacts energy production in New Mexico.

Phase 1 - The University of Utah (the Recipient), via their Institute for Clean and Secure Energy, shall pursue interdisciplinary, cradle-to-grave research and development of energy for electric power generation and for liquid transportation fuels from the abundant domestic resources of coal, oil sands, and oil shale. Emphasis will be on minimizing the environmental impacts associated with the development of these resources, including reducing the carbon footprint through the use of CO2 capture for subsequent storage (sequestration). Phases 2 and 3 - The Recipient, via their Institute for Clean and Secure Energy (ICSE), shall pursue research to utilize the vast energy stored in our domestic coal resources and do so in a manner that will capture CO2 from combustion from stationary power generation. The research is organized around the theme of validation and uncertainty quantification through tightly coupled simulation and experimental designs and through the integration of legal, environment, economics and policy issues. The results of the research will be embodied in the computer simulation tools which predict performance with quantified uncertainty; thus transferring the results of the research to practitioners to predict the effect of energy alternatives using these technologies for their specific future application. Overarching project objectives are focused in three research areas and include clean coal utilization for power generation retrofit; secure fuel production by in-situ substitute natural gas (SNG) production from deep coal seams; and environmental, legal, and policy issues.

The main research objective is to develop accurate and robust flame response models that can be incorporated into design tools for predicting longitudinal and transverse instabilities in lean premixed multi-nozzle combustors operating on high-hydrogen content (HHC) fuels. This will be accomplished through the coordinated application of state-of-the-art experimental techniques and reduced order modeling, and will be based on a strong collaborative effort involving research teams at both Georgia Tech and Penn State.

The objective of this work is to explore modifications to turbine endwall geometries that will both increase aerodynamic performance and reduce the potential for degradation due to deposition. The effort will include both experimental and computational components. Testing will include 1 to 2 laboratory tests per month for about 4 hours per test.

The objective of this project is to identify, develop, and characterize a viscous glass amenable to forming composite "self-healing" seals for SOFCs. If successful, Alfred researchers will collaborate with SECA Core Technology Program participants to develop and evaluate proof-of-concept engineered seals.

In this project, Foster Wheeler North America Corp. will conduct an in-depth materials test program to determine how, and to what extent, oxycombustion will affect the life of electric utility boiler tube materials. The program will determine what fireside corrosion mechanisms occur during oxycombustion and how much metal wastage they will cause. The program will involve computational fluid dynamics modeling to predict the gas compositions that will exist throughout and along the walls of oxycombustion boilers operating with high-, medium-, and low-sulfur coals. Laboratory testing will be conducted to determine the effects of these oxycombustion conditions on conventional boiler tube materials, conventional protective tube coverings, and alternative higher alloy tube materials and coverings.

Based on successful development and testing of a 65 kWthermal pilot-scale system under a previous DOE Cooperative Agreement, Alstom Power will engineer, procure, install, operate and test a 3 MWthermal chemical looping combustion prototype. The participant plans to install this prototype at their existing Power Plant Laboratory in Windsor, CT. The prototype will include a reducing reactor, an oxidation reactor, and process loops to transfer solids and oxygen between the two reactors. Alstom will use limestone as the oxygen carrier. Calcination of hot solids produced in the oxidation reactor will produce a concentrated stream of CO2 in lieu of the dilute CO2 stream typically found in flue gas from coal-fired power plants. This will enhance the ability to capture CO2 at coal-fired power plants. The information Alstom obtains from operation and testing will be used to develop a technical plan and cost estimate for a subsequent commercial demonstration project at a U.S. power plant.

In this project, Reaction Engineering International (REI) will manage a team of experts to perform multi-scale experiments, coupled with mechanism development and computational fluid dynamics modeling, for both applied and fundamental investigations in order to elucidate the impacts of retrofitting existing pulverized coal-fired utility boilers for oxycombustion. The primary objective of this program is to develop tools to characterize and predict impacts of CO2 flue gas recycle and burner feed design on flame characteristics (burnout, NOx, SOx and fine particle emissions, heat transfer), fouling, slagging and corrosion, inherent in the retrofit of existing coal-fired boilers for oxycoal combustion. Multi-scale test data will be obtained from oxycombustion experiments at 0.1 kWth bench-scale at Sandia National Laboratory (Albuquerque, N.M.), 100 kWth laboratory combustor-scale and 1.2 MWth semi-industrial scale combustors both at the University of Utah (Salt Lake City, Utah).

This project will investigate a Coal Direct Chemical Looping (CDCL) system to effectively capture CO2 from existing PC power plants by further advancing the novel CDCL technology to sub-pilot scale (25 kWt). Coal direct chemical looping is a technology designed to combust coal in a nitrogen free environment without using cryogenic air separation for oxygen production. The oxygen for combustion is provided by oxygen carrier particles that are oxidized in one reactor by air and then used to combust coal in another reactor. The movement of the particles from one reactor to the other gives the technology the name "chemical looping".

Alstom will develop an oxy-fuel firing system design specifically for retrofit to tangential-fired (T-fired) boilers and provide information to address the technical gaps for commercial boiler design. Several oxy-fuel system design concepts, such as internal flue gas recirculation and various oxygen injection schemes, will be evaluated for cost-effectiveness in satisfying furnace design conditions in a T-fired boiler. The evaluation will use an array of tools, including Alstom's proprietary models and design codes, along with 3-D computational fluid dynamics modeling. A techno-economic analysis will also be performed to assess the overall viability of concepts. Performance testing will be conducted in pilot-scale tests at Alstom's 15-megawatt (MW) T-Fired Boiler Simulation Facility and 15-MW Industrial Scale Burner Facility.

The overall objective of this project is to reduce the amount of fresh water needed to achieve power plant cooling by preventing the buildup of mineral scale on condenser tubes, thereby increasing the Cycle of Concentration (COC) in the cooling water system from the present operational value of 3.5 to at least 8. This will be achieved by developing scale-prevention technology that uses electrical pulse spark discharges to precipitate dissolved mineral ions (such as calcium and magnesium) and remove them from the cooling water.

The overall objective of the project is to reduce the cost of CO2 capture and achieve >95% CO2 recovery with oxy-combustion in existing PC (pulverized coal) power plants by integrating a unique combination of existing chemical processing technologies for contaminant removal (NOx, SOx, Hg) with Praxair's advanced CO2 compression and purification concept. Specific objectives are to carry out an experimental program to enable development and design of separate contaminant removal processes for plants burning high and low sulfur coals and high CO2 recovery process and to perform commercial viability assessment. Key benefits include high CO2 recovery even from plants with high air ingress and production of saleable sulfuric acid for plants burning high sulfur coal. The % increase in cost of electricity (COE) for retrofit plants is projected to be in 10 - 35% range when compared to a new coal fired power plant without CO2 capture.

The main objective of this project is to evaluate the potential feasibility of reusing three types of non-traditional water sources for cooling or process water for existing and planned (up to 2030) coal-based power plants in Illinois Basin. The sources are: (1) produced water from CO2-EOR operation; (2) coal-bed methane (CBM) recovery; and (3) active and abandoned underground coal mines.

This project is to develop a membrane separation technology to recover water vapor from power plant flue gas based on GTI's patented Transport Membrane Condenser (TMC) technique.

This project promotes the ongoing development and demonstration of the NETL Advanced Process Engineering Co-Simulator (APECS) tool kit. The APECS tool kit consists principally of a steady-state simulator for advanced power plants, which allows the DOE and its contractors to systematically evaluate various power plant concepts. This project advances and develops the APECS tool kit for an advanced carbon capture technology applications and dense-phase, chemical looping (CL) applications. At the completion of this program, the APECS tool kit will be capable of providing dense-phase riser co-simulations using a surrogate pseudo 1-D/2-D riser model as a ROM within CL and oxy-fired CFB systems.

In this project TDA Research, Inc., will produce and evaluate their low-cost solid sorbent developed in prior laboratory testing. A bench-scale CO2 capture unit will be designed and constructed, utilizing the developed sorbent. This unit will be tested on a coal-derived flue gas at Western Research Institute's (Laramie, Wyo.) coal combustion test facility. Mass and energy balances for a commercial scale pulverized coal-fired power plant retrofit with the CO2 capture system will be performed by Louisiana State University (LSU) with engineering assistance from Babcock and Wilcox (Barberton, Ohio).

This project is focused on determining the proof-of-concept for the Integrated Vacuum Carbonate Absorption Process (IVCAP) applied to post-combustion carbon dioxide (CO2) capture. The IVCAP uses potassium carbonate (K2CO3) as the solvent and carbonic anhydrase (CA) enzyme as a catalyst (promoter) to enhance the CO2 absorption rate into the solvent. The weak affinity of CO2 with K2CO3 allows CO2 to be stripped from the CO2-rich solution at a low temperature (104-158 oF) and pressure (2-9 psia) in the stripper. A unique feature of the process is in its ability to use either a waste steam or a low-quality steam from the power plant's steam cycle to provide the energy required for CO2 stripping. A preliminary process analysis shows that the electricity loss due to the steam extraction in the IVCAP is significantly lower (by up to 44%) compared to the monoethanolamine (MEA) process. The IVCAP can also remove sulfur dioxide (SO2) in the flue gas thus eliminating the need for a separate flue gas desulfurization unit required in the amine-based and amine-promoted absorption processes. In the IVCAP, the desulfurization product is potassium sulfate (K2SO4), which can be converted to potassium carbonate solution by reacting with hydrated lime.

In this project, SRI International, in collaboration with Advanced Technology Materials Inc. (Danbury, Conn.), will develop a novel, high CO2-capacity carbon sorbent with moderate thermal requirements for regeneration. The specific objectives are to validate the performance of the sorbent concept on a bench-scale system, perform parametric experiments to determine the optimum operating conditions, and evaluate the technical and economic viability of the technology. The information obtained from this project will be used to design a pilot unit that will treat a slipstream from an operating coal-fired power plant in a future phase.

The project will develop a distributed fiber optic sensors for the measurement of strain, temperature, and pressure. This will be accomplished for conditions expected in the next generation of high-efficiency Supercritical (SC) and Ultra Supercritical (USC) boiler systems. It will demonstrate sensor network performance and survivability when exposed to simulated conditions of an USC Boiler. The ability to distribute multiple sensors on a single fiber and to multiplex sets of sensors will be developed. The overarching goal is to move the multiplexed optical fiber sensor technology to a level where its large-scale application is made possible.

This project is to improve the performance of the Air2Air system that recovers water from coal-fired power plant cooling towers. The Air2Air was previously tested at the San Juan Generating Station under another DOE contract and found to work. This project will redesign the tower to make it lighter and less expensive so that it will be commercially viable.

A three dimensional (3D) high-speed electrical capacitance volume tomography (ECVT) system will be developed and demonstrated in this 3-year effort. The ECVT is a highly developed imaging system that utilizes simple equipment and high-level computing to render 3D images of multiphase flow systems. Traditionally, Electrical Capacitance Tomography (ECT) uses capacitance sensors for imaging multi-phase flow and requires that the sensors be large enough to pick up a signal. The traditional way of acquiring 3D images is to distribute the sensors in 3D, but since there is a limitation on sensor size, capacitance sensors can only be utilized for two dimensional (2D) imaging. In ECVT, 3D imaging was utilized by changing the sensor shape to provide 3D characteristics related to the shape of the sensors, not only their distribution. This way, 3D imaging can be obtained while satisfying the limitation on capacitance sensor size. Previous research did not follow this approach because it would lead to a highly non-linear image reconstruction problem that was difficult to solve. Tech4Imaging's image reconstruction technique (3D-NN-MOIRT) is capable of providing a solution to complexity problem, thus ECVT was realized for the first time. For Fossil Energy applications, a dedicated 3D ECVT is important for imaging fluidized-bed systems since multiphase flows are commonly encountered in industrial operations such as fluid-bed combustors, coal gasifiers, carbon capture processes, and Fischer-Tropsch synthesis. The inherently complex nature of multiphase flows requires a multi-dimensional measurement technique capable of providing real-time monitoring of the process dynamics and physical properties. The volume tomography acquires the 3D images directly from the measured capacitance data. This project will be completed through collaboration between Tech4Imaging and Ohio State University (OSU).

The objective is to develop a new ligand-functionalized core material (LFCM) for the removal of silica from impaired water and couple this technology to electodialysis reversal (EDR) for the 50% reduction of fresh water withdrawal for coal-fired power plants at less than $3.90 kgal of water.

The objective of this project is to advance the design and construction of a mini Fischer-Tropsch refinery at the University of Kentucky Center for Applied Energy Research (CAER). The unit is intended for use as a low-cost test bed for new concepts. It will provide open-access facilities and information in the public domain to aid the wider scientific and industrial community, and provide a means to independently review vendor claims and validate fuel performance and quality.

This project will investigate the effects of contaminants present in synthesis gas produced by gasification of coal and biomass mixtures on the performance (activity and selectivity) and life of certain water-gas-shift (WGS) and Fischer-Tropsch (F-T) catalysts. The impact of these potential contaminants on commercially available and generic (prepared based on scientific and patent literature) WGS and F-T catalysts will be investigated by conducting a thermodynamic analysis to identify these contaminants and determine their potential interactions with the catalysts and by conducting laboratory and bench-scale reaction tests to determine the rate of deactivation and its impact on projected replacement rates for the WGS and F-T catalysts. Catalyst samples will be sent to University of Kentucky's Center for Applied Energy Research (CAER) to be characterized. A trade-off analysis will be conducted to determine whether additional synthesis gas cleaning or replacement of the catalyst is the more cost-effective option.

The overall objective is to evaluate, for treated municipal wastewater, the benefits and costs of implementing tertiary treatment of the wastewater prior to use in recirculating cooling systems versus an expanded chemical regimen for managing the chemistry of the cooling water with municipal wastewater as makeup.

This project will address potential gas-fired turbine damage due to coal contaminants in an Integrated Gasification Combined Cycle (IGCC) power plant. The main research objectives are to understand the airfoil coating damage mechanisms due to coal contaminant deposits and to apply a previously-successful approach to mitigating any possible damage in the field. Ohio State University will employ a strategy very similar to a previously-successful one they developed to mitigate attack by dust and sand on aero engine coatings.

The overall objective of this project with Georgia Institute of Technology is to understand the role of cathode surface properties on Solid Oxide Fuel Cell (SOFC) performance. SOFC cathodes are responsible for the particularly difficult reaction whereby oxygen from the air in a fuel cell is converted into an ion which then migrates across a solid membrane to then react with fuel to form water or CO2. In this project, cathode materials will be coated with catalysts and characterized with a variety of advanced analytical techniques. The samples will also be tested under SOFC conditions to determine their performance.

The Shallow Carbon Sequestration Pilot Demonstration Project is a cooperative effort involving City Utilities of Springfield (CU), Missouri Department of Natural Resources (MDNR), Missouri State University (MSU), Missouri University of Science & Technology (MS&T), AmerenUE, Aquila, Inc., Associated Electric Cooperative, Inc., The Empire District Electric Company, and Kansas City Power & Light. The purpose of the project is to assess the feasibility of carbon sequestration at Missouri power plant sites. The six electric utilities involved in the project account for approximately 99% of the electric generating capacity in the state of Missouri. The pilot demonstration will evaluate the feasibility of utilizing the Lamotte Formation for carbon sequestration at individual power plant sites across the state. Given that the depth of the Lamotte is less than the general depth that carbon dioxide can be injected in supercritical phase, injection would have to occur in the gas phase. Much of the research planned in the pilot demonstration is focused on characterizing the interaction of gaseous carbon dioxide with the groundwater and the host rock and determining how, and to what degree, hydrodynamic, solubility, and mineral trapping will occur. The pilot demonstration can be divided into five separate phases: Phase I involved the initial analysis of Lamotte core at MS&T in 2006. Phase II will involve site exploration and site characterization activities (seismic survey, drilling, coring, pumping tests, groundwater monitoring) at the SWPS project site. Phase III will involve studies at MDNR, MSU, and MS&T, as well as preparation of the injection well permit application at City Utilities. Phase IV will involve construction of the Class V injection well, installation of temporary injection equipment (compressor and tankage), and performance of the injection test. Phase V will involve assimilation of all project data and findings into a comprehensive final report.

This is a phased approach to building wetlands as a cooling mechanism for power plant water. In Phase I, the participant will model wetland cooling predictions, prepare topical reports on the use of wetlands for powerplant cooling and design a pilot scale wetland. This phase is followed by a DOE decision point to continue the project. In Phase II, the participant will create a pilot-scale wetland (of 5 acres) at a host power plant, and conduct measurement and monitoring to verify the model accuracy.

The objective of the proposed work is to design, develop, and demonstrate a condition monitoring sensor network comprising a high temperature wear sensor and multi-functional magnetic sensor to monitor cracks in hot section combustion components in real time. The wear and crack monitoring sensors will be combined with the basic control system sensors to provide a modular sensor network for condition monitoring and assessment of combustion hardware. The condition monitoring system development will be a collaborative effort of Siemens Energy, K Sciences, and JENTEK Sensors that will be managed by Siemens Energy, Inc.

The overall objectives of the proposed research are to prepare novel mixed-matrix membranes based on polymer composites with nanoparticles of zeolitic imidazolate frameworks (ZIF) and related hybrid frameworks. Membranes containing these new materials will be used to evaluate separations important to coal gasification (e.g. H2, CO, O2, CO2). The goal is to exploit the high surface areas, adsorption capacities, and selectivities of the nanoporous ZIF additives to achieve unprecedented transport of gases critical to coal processing. The performance of the membranes under operating conditions defined by 2015 DOE targets will be evaluated.

This application proposes to use a plasmonics based all-optical sensing technique which utilizes the optical properties of tailored nanomaterials as the sensing layer. This novel and alternative approach to gas sensing under harsh environmental conditions is a much simpler design as the sensing system does not require the development of harsh environment compatible ohmic contacts, nor does it require high temperature electronics, which typically suffer from reliability and stability problems. The objectives of this project will be to further optimize these characteristics while developing a detailed understanding of the sensing mechanism as a function of temperature and humidity.

The project is to develop new types of high temperature (>500C) fiber optic chemical sensors for monitoring of coal-derived gases. This will be accomplished by physically and functionally integrating advanced nano ceramic materials with fiber optic devices. The first type is a Long Period Fiber Grating (LPFG)-coupled self-compensating interferometer sensor. The second type is an Evanescent Tunneling sensor. Both types of sensors are highly selective and targeted through application of nanocrystalline thin film coatings of doped-ceramics at specific gas molecules. This project focuses on sensors for Hydrogen (H2) and Hydrogen Sulfide (H2S) detection at high temperatures (>500C) and elevated pressures up to 250 psi.

The overall goal of this project is to improve the performance and accuracy of the MFIX code that is frequently used in multiphase flow simulations. The specific objectives of the project are to use first principles embedded in a validated Direct Numerical Simulation particulate flow program that uses the Immersed Boundary method (DNS-IB) in order to establish, modify and validate needed energy and momentum boundary conditions for the MFIX code.

The goal of this project is to investigate a novel approach for in situ synthesis of bimetallic nanostructured mesoporous silica materials and to study its applications for production of hydrogen. The objectives of this exploratory research are: 1. One-step synthesis of highly ordered functionalized mesoporous silica materials using amalgamation of noble and non-noble metal clusters. 2. Characterization of the mesoporous materials using SEM, AFM, TEM , FT-IR, Si-NMR, EDX, XRD and BET surface area measurements. 3. To utilize synthesized novel bimetallic nanoparticles in mesoporous silica for SRM to produce hydrogen. 4. To minimize deactivation of the catalyst due to CO formation by optimizing the catalyst loadings through fundamental studies.

The objective of this project is to use a science based systems engineering approach to design iron based superalloys capable of operating in the temperature range of 873 to 1033 deg Kelvin. The project will use computational tools supported by experiments to study phase stability, microstructure design and coarsening dynamics with a goal to designing superalloys to enhance power generation efficiencies.

Air Products and Chemicals, Inc., (APCI) is currently developing ion-transport membrane (ITM) oxygen separation technology for large-scale oxygen production and for integration with advanced power production facilities, including gasification facilities. The ITM-based oxygen production process uses dense, mixed ion- and electron-conducting (MIEC) materials that can operate at temperatures as high as 900 degrees Celsius (°C). The driving forces for the membrane oxygen separation are determined by the oxygen partial-pressure gradient across the membrane. The energy of the hot, pressurized, non-permeate stream is typically recovered by a gas turbine power generation system. The development of the ITM process will support reduced capital cost and parasitic load of air separation systems compared to that of currently available cryogenic air separation technology. Because air separation is a critical component of the gasification process for power production, any reduction in the cost of this process component will in turn reduce the overall cost of gasification, thereby making the process more competitive. APCI has a co-current ITM project, FE0012065.

The Center for Photonics Technology at Virginia Tech has successfully developed a novel temperature sensor capable of operating at temperatures up to 1600 degrees Celsius (°C) and in harsh conditions. The sensor uses single-crystal sapphire to make an optically-based measurement and will fulfill the need for the real-time monitoring of high temperatures created in gasification processes. Based on a successful laboratory demonstration of a optical sapphire based sensor, Virginia Tech's CPT was awarded follow on development work to design construct and test a prototype sensor that could be installed in coal gasifiers. The improved version of the sensor is intended to be more robust, accurate and reliable for extended operation in a coal gasifier and will be evaluated at a full scale gasifier (e.g. Eastman Chemical).

CONSOL Energy Inc. is demonstrating a novel drilling and production process that reduces potential methane emissions from coal mining, produces usable methane (natural gas), and creates a storage option for carbon dioxide (CO2) in unmineable coal seams. CONSOL's project employs horizontal drilling to drain coalbed methane (CBM) from a mineable coal seam and an underlying unmineable coal seam. Upon drainage of 50-60 percent of the coalbed methane, some of the wells will be used for CO2 injection to store the CO2 in the unmineable seam, while stimulating additional methane production. The technique starts with a vertical well drilled from the surface followed by a guided borehole that extends up to 3,000 feet horizontally in the coal seam, allowing for production over a large area from relatively few surface locations.

The project involves development of a 200 acre area involving two coal seams. The lower, unmineable seam is being degassed and injected with CO2. The upper, mineable seam is being degassed to produce coalbed methane, thus avoiding methane emissions when the seam is mined. The upper, mineable seam is being isolated from the lower, unmineable seam to prevent CO2 migration from the unmineable seam into the mineable seam.

Researchers will identify materials that limit operating temperatures and thermal efficiency of coal-fired plants; define and implement ways of producing improved alloys, fabrication processes and coating methods that allow boilers to operate at 1400 degrees Farenheit (?F); participate in the certification process of the American Society of Mechanical Engineers (ASME) and generate data to lay the groundwork for ASME code approved for alloys, where necessary; define issues affecting the design and operation of ultrasupercritical (USC) plants operating at 1600 ?F; develop cost targets; and promote the commercialization of alloys and processes expected to emerge from this effort, working with alloy makers, equipment vendors and utilities.

The objectives of this project are: 1. Develop a SOFC power system for a range of fuels and applications 2. Develop and demonstrate technology transfer efforts on a 5kW stationary distributed power generation system that incorporates reforming of methane and natural gas. 3. Develop a 5kW auxiliary power unit for heavy duty trucks and military power applications. 4. Develop system modeling, stack design and cell evaluation for a high efficiency coal based SOFC gas turbine hybrid system

This three-phase Solid State Energy Conversion Alliance (SECA) Coal-Based Systems (Industry Team) project led by Fuel Cell Energy will develop low cost solid oxide fuel cell (SOFC) technology for use in highly-efficient central generation power plants fueled by coal synthesis gas. Anode-supported planar SOFC technology is being developed by Versa Power Systems, Inc. WorleyParsons has provided direct support of Integrated Gasification Fuel Cell (IGFC) system analysis.

The objectives of this project are to improve the availability and efficiency of gasification-based power plants, and to reduce plant capital and operations costs. The specific objectives of this project towards these over-arching objectives are to: 1. Demonstrate high pressure, solids feed system including long-life rapid-mix injectors, flow splitting, and operation of a prototype feed pump. 2. Test cooled refractory liner coupons. This cooled refractory is anticipated to result in an operational life exceeding three years. 3. Perform conceptual design and hardware definition of a novel 18 tons per day (tpd) highly efficient, long life entrained flow gasifier. Of these three specific objectives, the active work has focused only on the first item: development of the high-pressure, dry feed pump, including the detailed design, construction, and testing of a 600 ton per day (tpd) prototype. The project's primary tasks involve conceptual design, sub-scale testing, engineering design, construction, and operation of a prototype pump. This prototype pump design baseline configuration will be 400 tpd capacity and 1,200 psi outlet pressure. To achieve project objectives, the prototype pump is also designed to ramp up to 600 tpd operation and to provide data needed to predict commercial scale operation constraints. Testing is planned for performance tests on bituminous coal, PRB coal, high moisture lignite coal, and petcoke at up to 1,200 psi to demonstrate reliable pump operation across a high pressure gradient (applicable to 1,000 psi gasifier), to define the commercial target for pump size, to assess adequate safety factor for pump, to validate the pump models, and to provide data for a final benefits analysis.

The U.S. Department of Energy (DOE) is providing Financial Assistance under Round II of the Clean Coal Power Initiative (CCPI) for a large utility, commercial-scale, coal-based Integrated Gasification Combined Cycle (IGCC) electric power generating facility to be located near Taconite, Itasca County, Minnesota. MEP-I, LLC, a project company of Excelsior Energy, Inc., will design, construct, and operate the Mesaba Generating Station in two 606 MWe (net) phases, of which the DOE-defined demonstration project is Phase I. Mesaba will demonstrate the ConocoPhillips E-Gas™ gasification technology in a first-of-a-kind, multiple-train configuration incorporating findings from more than a decade of optimization and experience based on the Wabash River Coal Gasification Repowering Project, including: (1) gasifier scale-up; (2) increased system pressure; (3) increased slurry percentage to the second-stage gasifier; and, (4) enhanced by-product and contaminant removal systems. Excelsior's original request was for $150 million in Federal cost-shared funding. The project was selected at a level of $36 million due to the availability of funds.

Southern Company Services, Inc., in a team effort with Mississippi Power Company and Kellogg Brown and Root, LLC (KBR), will design, construct, and operate a coal-based TRIG Combined Cycle power plant with 65% CO2 capture at a site in Kemper County, MS. The estimated nameplate capacity of the plant will be 830 megawatts electrical (MWe) with a peak net output capability of 582 MWe. TRIG is based on KBR's catalytic cracking technology, and is cost-effective when handling low rank coals and when using coals with high moisture or high ash content. These coals make up half the proven reserves in both the United States and the world. The estimated 3 million tonnes of CO2 per year captured from the power plant would be transported via pipeline for beneficial use in existing enhanced oil recovery (EOR) operations in Mississippi.

The U.S. is the largest producer of mining products in the world. The Center for Advanced Separation Technologies (CAST) was established to develop technologies that can be used by the U.S. mining industry to create new products, reduce production costs, and meet environmental regulations. CAST is a consortium of seven universities, with the purpose of conducting both fundamental and applied research that has crosscutting applications in the mining industry. The university members include Virginia Tech; West Virginia University; Montana Tech of University of Montana; New Mexico Institute of Technology; University of Nevada, Reno; University of Utah; and University of Kentucky.

The Big Sky Regional Carbon Sequestration Partnership is building on the work conducted in the Characterization Phase (2003-2005) with a focus on geologic and terrestrial field validation tests that assess the relative efficiency of alternative sequestration options, prove the environmental efficacy and sustainability of sequestration, verify regional carbon dioxide (CO2) sequestration capacities and satisfy field test permitting and regulatory requirements. Data from validation tests will be integrated into a geographical information system (GIS) tool that will assist industry and regional planners to optimizing energy development strategies. The highlight of the Phase II effort is a pilot-scale test to inject approximately 1,000 tons of supercritical CO2 into a deep basalt formation (Grande Ronde Basalt) in western Walla Walla County, in eastern Washington State. The highlight of the Phase III effort involves the extraction of ~1 million tonnes of naturally-occurring CO2 from the top of Kevin Dome, a prominent geologic structural trap in northwest Montana, and re-injection of the CO2 into saline aquifers that occupy the stratigraphically-lower portions of the dome.

The Midwest Geological Sequestration Consortium (MGSC) is performing small scale CO2 injection tests in Illinois, Indiana, and Kentucky as part of their Phase II effort to test injection into coals and mature oil reservoirs. For Phase III MGSC will inject 1 million metric tons of CO2 from ADM's corn processing facility in Decatur, Illinois into the Mount Simon Sandstone. For the past 2 years MGSC has been characterizing the injection site in preparation for injection operations. The CO2 will be injected over 3 years starting in 2011, followed by fate monitoring for the next 3 An array of monitoring technologies will be used to baseline and monitor the CO2 in the reservoir and at the surface.

The Midwest Regional Carbon Sequestration Partnership (MRCSP) has been established to assess the technical potential, economic viability, and public acceptability of carbon sequestration within a region consisting of nine contiguous states: Indiana, Kentucky, Maryland, Michigan, Ohio, Pennsylvania, West Virginia, New Jersey and New York. A group of leading universities, state geological surveys, non-governmental organizations and private companies, led by Battelle Memorial Institute, has been assembled to carry out this research. The MRCSP's Validation Phase II research program will center on taking the large theoretical sequestration potential identified in the MRCSP's Characterization Phase I (2003-2005) research program and, through a series of validation tests, show how the region's large, well-distributed sequestration potential can be used to simultaneously advance economic growth and environmental protection. In Phase III, the Development Phase, this partnership, led by the Battelle Columbus Laboratories, has proposed a primary and an optional large scale injection site. Evaluation of the primary site, Michigan Basin is expected to be initiated in late 2010 and ready for injection in 2012 (early FY 2013).

SECARB investigates a stacked sequence of hydrocarbon and brine reservoir intervals in the Gulf Coast, where EOR with carbon dioxide (CO2) can serve as an economic driver in establishing the CO2 infrastructure. (2) A Coal Seam Project will be conducted for validation of sequestration opportunities in the Central Appalachian Basin and the Black Warrior Basin, where CO2 enhanced coal bed methane (ECBM) recovery operations can add economic value, and where unmineable coals can provide sequestration opportunities. (3) A Saline Aquifer Test Center Project will be conducted that focuses on validating geologic storage in a saline aquifer in the Mississippi Salt Basin in close proximity to a Southern Company coal-fired power plant in The Electric Power Research Institute's Test Center program.

PCOR Partnership is one of seven Regional Carbon Sequestration Partnerships competitively awarded as part of a national plan to mitigate greenhouse gas emissions. Phase II PCOR sites included: Terrestrial work in the Prairie Pothole Region; EOR work at Zama in Alberta, Canada; a huff 'n' puff test in North Dakota; and a lignite test in North Dakota. Phase III PCOR sites include: saline formation storage at Fort Nelson, British Columbia, Canada; and EOR at the Bell Creek site in Montana.

Under the American Recovery and Reinvestment Act (ARRA) funded program, GE Power & Water, along with GE Global Research Center (GE) will develop advanced industrial-frame turbine technology for hydrogen fueled turbine machinery. These turbines can be utilized in conjunction with pre-combustion carbon capture systems to effectively reduce carbon emissions from a variety of industrial applications. This project includes the following work: 1. Advanced Hydrogen Combustion System: The combustion work in the project will develop a new combustion system that will enable industrial gas turbine applications with carbon capture and storage (CCS) to reach higher efficiencies through higher firing temperatures with low NOx. The developed combustion system will be validated in a gas turbine operating at full conditions. The validation step from testing a full-scale combustion can in the laboratory, to testing the multi-can configuration on the gas turbine, will enable accelerated transition of the technology to future gas turbine designs. 2. Materials: The materials work will develop alloys that are specifically tailored to withstand elevated temperatures in the hot gas path in the high-moisture, and potentially highly corrosive environments of hydrogen-fueled industrial applications with CCS. This will enable industrial gas turbine applications with CCS to achieve improved efficiency through higher firing temperature while preserving traditional hot gas path component durability. 3. Sensors: The sensors work will focus on utilizing and integrating a variety of advanced sensor technologies into gas turbine control and operation. This will enable the gas turbine to be operated with real-time knowledge of actual parameters that are affecting component conditions and operation. Therefore, industrial gas turbine applications with CCS will be able to achieve improved efficiency and operability, and reduced emissions. 4. Turbine Airfoil: The turbine airfoil work will develop technology that reduces required cooling flows to enable industrial gas turbine applications with CCS to achieve improved efficiency.

Under the American Recovery and Reinvestment Act (ARRA) funded program, Siemens Energy will focus on advancing state-of-the-art large natural gas fired turbine technology to produce turbines specifically designed for operation on hydrogen and syngas fuels derived from industrial processes that capture a large percentage of CO2. Advanced technologies and concepts will be evaluated, down selected, and validated. The advanced technologies, component designs, and manufacturing processes will be developed and verified in sub-scale and full-scale tests and process verifications to demonstrate that the program goals can be achieved. Some of the key enabling technologies needed are as follows: Fuel-flexible, ultra low NOx, long-life combustion system operating at the increased firing temperatures needed to achieve high efficiency. Siemens will work to develop a premixed combustion system capable of operating on hydrogen fuel at high temperatures with minimal dilution flow. As part of this development, modeling tools for thermal acoustics and computational fluid dynamics will be adapted for hydrogen fuels and validated with test data. The primary path for the hydrogen combustor is a modification of the current Siemens premixed natural gas burner to operate on hydrogen. In addition, as risk mitigation, several alternative combustion technologies will be evaluated to determine if they can provide an improvement for high-temperature hydrogen operation. Development and optimization of higher temperature material system (base alloy, bond coat, and thermal barrier coatings [TBCs]) capabilities that allow operation in challenging environments, thus ensuring that the turbine components achieve high reliability and long life. Advanced manufacturing processes and techniques essential to producing the novel turbine cooling schemes that are being pursued in this program. Siemens will be producing full-sized engine parts using advanced core making technology, performing investment casting trials, conducting destructive and non-destructive evaluations, machining prototype parts using a proposed production process and conducting full-scale engine testing on final products. New sensors and diagnostics to allow more efficient, fuel-flexible, and safe gas turbine operation. Customer interviews determined key sensing needs and sensor specifications for these needs. Based on these results, Siemens will work with sensor vendors to design, develop, and validate sensor designs for engine validation or use in on-line control.

Clean Energy Systems (CES) has developed an oxy-fuel power generation concept to enable near zero-emission power generation from natural gas and syngas. The core of the technology is a high-pressure oxy-combustor that produces a steam/carbon dioxide (CO2) working fluid for expansion in a turbine. This project is a partnership with Department of Energy (DOE) award DE-FC26-05NT42646 to Siemens Power Generation to develop high-temperature turbines that would be powered by working fluid from the oxy-combustor. The project has also received funding from the American Recovery and Reinvestment Act of 2009 (ARRA) for advancing the oxy-fueled turbine technology for commercial industrial oxy-fueled plants which utilize CO2 capture and storage technologies. This 36 month effort to be performed in parallel to the existing Phase II BP2 and is isolated from the rest of Phase II due to the application focus and unique set of tracking and reporting requirements associated with its ARRA funding source.

Southwest Research Institute (SwRI), partnered with Dresser-Rand, is developing improved methods to compress carbon dioxide (CO2). The high pressure ratio compression of CO2 results in significant heat of compression. Because less energy is required to boost the pressure of a cool gas, both upstream and inter-stage cooling are standard industry practices when compressing gases for geologic injection. This project will evolve optimal compressor thermodynamic cycles and associated equipment to boost the pressure of CO2 to wellhead pressures, approximately 2,200 pounds-per-square-inch-gauge (psig). This project is divided into two phases, with plans to solicit applications for a full-scale compression demonstration at an existing or proposed integrated gasification combined cycle (IGCC) plant. Phase I (Scoping and Modeling, which has been completed) was focused on the CO2 compressor technology to determine performance characteristics. Phase II (Bench Scale Testing and Evaluation) focused on evaluation and testing of the CO2 compressor technology. Phase III will focus on the scale up and testing of the CO2 compressor with intercooled diaphragm in a loop with the liquid CO2 pumping system.

West Virginia University Research Corporation (WVURC) is investigating the long-term environmental and economic impacts of coal liquefaction in China.

This research and development project will construct and operate a 50 MMbtu (approximately 5 MW) test facility in Hammond, IN with Jupiter Oxygen oxy-fuel technology and Department of Energy National Energy Technology Laboratory's [NETL] Integrated Pollution Removal [IPR] technology. Operation of the facility will provide developmental engineering and design data for the research retrofit of future coal-fired power plants , to advance the creation of a virtually zero emissions power plant for NOx, SOx, particulate and mercury, as well as one capture ready for CO2 sequestration.

A one-box process for hydrogen production will be developed based upon the carbon molecular sieve (CMS) membrane. In this one-box process unit, syngas will be shifted to CO2 and hydrogen, and the hydrogen will be separated via the CMS membrane. A mathematical model will be developed by the University of Southern California to aid in the process development. The process will first be demonstrated in a bench-scale unit. Then it will be tested at pilot scale in the National Carbon Capture Center facilities in Wilsonville, AL.

The objective of this project by WPI is to develop advanced process intensification technologies that reduce the number of unit operations required for hydrogen production from coal gases produced from coal gasification. Process intensification will reduce the production of pure hydrogen from synthesis gas to two unit operations consisting of an advanced synthesis gas clean-up system and a composite Pd-Pd/alloy membrane WGS shifter, which could be integrated downstream in the hydrogen producing coal gasification system. The high pressure CO2 from the membrane shifter would be appropriate for recycling, sequestration, and/or conversion to industrially useful products and the creation of a natural CO2 sink.

The objective of the proposed research is to develop a validated design tool that can predict flashback and combustion instability in lean premixed combustors operating on coal-derived, high-hydrogen fuels. Its focus upon high fidelity simulations, coupled with validating measurements, and development of reduced order models will significantly improve understanding of these phenomenon and capabilities for predicting their occurrence.

The objective of this project is to develop solid state based materials joining technologies for high temperature alloy tubes suitable for heat exchanger applications in Rankine, Brayton, HIPPS and IGCC power systems concepts. Two separate techniques a) Inertia Welding and b) Magnetic Pulse Welding are proposed for butt and lap joint configurations. The materials of interest are an ODS alloy (MA956) and Ni-base alloy (IN740) alloy tubes in similar and dissimilar metal/alloy joint configurations. The research program outlined here is iterative in nature and will systematically explore 1) respective joining techniques to develop 2) robust similar/dissimilar metal tube joints with 2) maximum creep strength performance at the intended service temperature range. This research program will leverage the expertise of industrial vendors Interface Welding, Carson (CA) and Magneform Corporation, San Diego (CA).

Praxair determined (under a prior agreement with DOE) that the cost of CO2?capture utilizing oxygen transport membrane (OTM) air separation integrated with oxy-combustion is competitive with other CO2capture processes when applied to large power plants. This work also demonstrated that durable OTMs for oxy-combustion can be fabricated to survive and operate reliably in a fuel environment. Praxair observed a zero percent failure rate for the OTM membranes during prior testing; however, the highly durable materials selected for the OTM reactors require substantial development in order to improve the oxygen flux through the system while maintaining durability and reducing manufacturing costs. In the first stage of this project, Praxair will further develop high-performance materials used for OTMs, optimize and test process configurations, validate manufacturing capabilities, and produce a preliminary engineering design for an OTM pilot plant system. With the addition of ARRA funding, the second stage of this project will focus on operating OTM modules in syngas and conducting oxy-combustion development- and pilot-scale tests incorporating critical system components required of commercial systems. Praxair will develop and operate a robust and reliable OTM module that will provide the foundation for commercial deployment of reactively driven ceramic membrane systems. Praxair will develop first-generation OTM modules and test them in a developmental-scale, fully integrated, multi-module syngas system producing 160,000 standard cubic feet per day (scfd) of syngas and incorporating components of a commercial system. Praxair will develop second-generation OTM modules incorporating improvements identified through module testing, and test them in a pilot-scale skidded, multi-module syngas system as well. All testing and modeling results will be evaluated to develop preliminary cost estimates for a demonstration-scale syngas system and a preliminary design for pilot-scale oxy-combustion system.

This project is designed to demonstrate the performance and fabrication of a technically and economically viable pre-combustion-based carbon dioxide (CO2) capture system based on polybenzimidazole (PBI) membranes. In addition, SRI International proposes to optimize the plan for integration of a PBI capture system into an integrated gasification combined cycle (IGCC) plant. To that end, larger-scale/larger-throughput membrane-based separation modules will be designed, fabricated, and evaluated during the course of the project. SRI International will develop a commercialization plan that addresses technical issues (e.g., a roadmap for the scale-up of production of PBI membrane modules) and business issues (e.g., insurance considerations and potential joint venture opportunities) to outline a clear path for technology transfer of the PBI membrane technology.

The University of Notre Dame and its partners are working to continue development of novel ionic liquid absorbents and an associated process for the removal of CO2 from coal-fired power plant flue gas. Ionic liquids are salts that are liquid in their pure state near ambient conditions. In a previous NETL-funded project, Notre Dame demonstrated that ionic liquids can be engineered to have very high physical solubilities and can also be made to form chemical complexes with CO2. Due to their chemical diversity, ample opportunities should exist to tailor and optimize the properties of ionic liquids for CO2 capture. Having shown their potential in the previous project, researchers will work in this project to take the next step in the development process.

Alstom Power Plant Laboratories will develop models of their Chemical Looping Process and devise a model based control technology for managing multiple and reacting multiphase flow loops. The development team will develop models, reduce the models for fast operation and create model based controllers for the loops. The algorithm development for these Model Predictive Controllers (MPC) will be tested using bench scale systems to determine the validity and improvement to system performance that MPC can make when operating complex processes.

Staged combustion produces reducing/sulfidizing conditions that are particularly corrosive to the lower furnace walls. On the other hand, the conditions at superheaters/reheaters are typically oxidizing. However, due to relatively high metal temperatures, the superheater/reheater tubes tend to suffer from severe coal ash corrosion attack due to alkali metals contained in the ash. The problem will be further intensified when the steam outlet temperatures of advanced combustion systems are to increase significantly. To address these corrosion concerns, Babcock & Wilcox (B&W) intends to develop corrosion models in this program that are capable of predicting lower furnace and superheater/reheater corrosion wastage. Because corrosion attack is thermally activated, the effect of temperature will also be investigated. Ohio State University faculty will support B&W's efforts by contributing their technical expertise in the area of high temperature corrosion.

This project supports a Joint Program for Research and Development for Fossil Energy-Related Research at the Energy & Environmental Research Center (EERC), with a minimum yearly overall 20% non-federal cost-share, to conduct basic, fundamental, and applied research that will assist industry in deploying and commercializing efficient, nonpolluting energy technologies that can compete effectively in meeting requirements for clean fuels, chemical feedstocks, electricity, and water resources in the 21st century. This project supports DOE goals by advancing scientific knowledge and technical development and demonstrations of technologies that ensure sustainable supplies of affordable energy and clean water and preservation and restoration of the environment. The performance goals support the DOE goals of reducing dependency on foreign sources of energy, making fossil energy systems more efficient, and capturing and sequestering greenhouse gases.

The overall objective of the WRI Cooperative R&D program is to conduct both fundamental and applied research that will assist industry in developing, deploying, and commercializing efficient, nonpolluting fossil energy technologies that can compete effectively in meeting requirements for clean fuels, chemical feedstocks, electricity, and water resources in the 21st century. The program supports and contributes to the energy science and technology mission of DOE/FE: 1.Increase the production of U.S. resources. 2.Enhance the competitiveness of U.S. technologies. 3.Reduce dependence on foreign energy supplies and strengthen National and regional economies. 4.Minimize environmental impacts of energy production and utilization processes.

Through its core research and development program administered by the National Energy Technology Laboratory (NETL), the U.S. Department of Energy (DOE) emphasizes monitoring, verification, and accounting (MVA), as well as computer simulation and risk assessment, of possible carbon dioxide (CO2 ) leakage at CO2 geologic storage sites. MVA efforts focus on the development and deployment of technologies that can provide an accurate accounting of stored CO2 , with a high level of confidence that the CO2 will remain stored underground permanently. Effective application of these MVA technologies will ensure the safety of geologic storage projects with respect to both human health and the environment, and can provide the basis for establishing carbon credit trading markets for geologically storing CO2 . The new technology is based on the concept of “smart fields,” which is rapidly gaining support and popularity in the oil and gas industry. Smart fields integrate digital information technology with the latest monitoring techniques to provide continuous knowledge and control of reservoir operations and processes. Under this concept, hundreds of millions of dollars have been invested to successfully develop highly sensitive PDGs that are capable of operating in harsh environments for long periods. The PDGs collect and transmit high-frequency data streams in real time to remote control centers to be analyzed and used for reservoir management. The project team will use the pattern recognition power of state-of-the-art Artificial Intelligence and Data Mining (AI&DM) technology to develop a methodology, residing in a computer program, to recognize patterns from simulated realistic pressure data acquired from PDGs located within the reservoir model (Figure 1). This software will be capable of, but not limited to, locating point sources within a reservoir from which CO2 is leaking based on changes in pressure data. The methodology will autonomously cleanse and summarize raw data collected from in-situ pressure gauges, to prepare the data for processing and analysis. Upon completion, the methodology will be validated by its ability to accurately identify the location of simulated leakage points in a model of an existing heterogeneous reservoir. Once the approximate location of potential CO2 leakage is identified, the information will be communicated via e-mails, text messages, or other means to those performing “at” or “near” surface monitoring locations for more precise detection and analysis. The main objective of this project is to develop the next generation of intelligent software that is able to take maximum advantage of the data collected by PDGs to continuously and autonomously monitor and verify CO2 storage in geologic formations as part of the effort to assure CO2 storage permanence in the subsurface. Further, the project team will investigate the feasibility of using this technology to monitor the growth and advancement of the CO2 plume during the injection process.

The main objective is to produce amorphous ribbons from non-precious metal alloys. These amorphous membranes are expected to work towards meeting all 2015 separation targets, such as of flux (300 ft3/hr/ft2), temperature (200-500 ºC), sulfur tolerance (>100 ppmv), and cost (<$100/ft2). Moreover these membranes will not use Pd coatings. The project consist of developing multiple metal-alloy ribbon membranes for evaluation and down selection. The selected membranes will then be tested in sygas and provided to NETL for testing. and Fabrication of hydrogen permeation membranes will be performed through the collaboration of the University of Nevada, Reno (UNR) and CSIRO in Australia.

Using high-fidelity fluid-dynamics models as input, Reaction Design will extend existing technology that is designed to automatically extract equivalent reactor networks (ERNs) from the CFD solution. The extraction is based on certain criteria for grouping regions of similar kinetic behavior. The ERNs are composed of idealized reactors (e.g., perfectly stirred and/or plug-flow reactors) that interact through mass-flow and heat-transfer connections to represent the complex flow. In contrast to the CFD simulations, however, the ERNs allow inclusion of detailed kinetics representation of the reacting-flow process, including particle-gas interactions, gas combustion and emissions production. While this technology has been established for gas-turbine combustors, one aim of this project will be to extend the methodology to gasifiers. A key component of this project is to encapsulate the CHEMKIN-based ERN models as CAPE-OPEN-compliant objects that can be used in general flow-sheet simulation software. By combining existing detailed-kinetics reactor-network capability from CHEMKIN-PRO with CAPE-OPEN interface standards, state-of-the-art kinetics modeling will be enabled within flow-sheet type simulations. This will be the basis for developing accurate reduced-order-models for gasification/combustor processes. Through the Cape-Open interface, the CHEMKIN reactor or reactor network will be considered as a Unit Operation. By adopting the Cape-Open architecture, such a representation of a combustor or gasifier can be combined with other unit operations to allow a plant or system simulation. In this way, more accurate chemistry will allow consideration of chemical details such as carbon conversion efficiency and syngas composition in the overall system design.

The overall project objective is to develop an innovative, low-cost CO2-capture technology for integrated gasification combined cycle-based power plants that is based on absorption on a high-capacity and low-cost aqueous ammoniated solution. SRI, in collaboration with Bechtel Hydrocarbon Technology Solutions, Inc., is conducting a two-phase effort to develop and evaluate SRI Ammonium Carbonate-Ammonium Bicarbonate (AC-ABC) technology to capture CO2 and hydrogen sulfide (H2S) from coal-based gasification processes and Bechtel Pressure Swing Claus Sulfur Recovery Unit (BPSC) which will convert H2S to elemental sulfur. The first phase tested the technology in a bench-scale batch reactor to validate the concept and determine the optimum operating conditions for a small pilot-scale reactor. The second phase will include the design and fabrication of a small pilot-scale test system and testing of the capture technology on a slipstream of real shifted syngas from the National Carbon Capture Center (NCCC) in Wilsonville, Alabama.

The study will develop an active source reflection seismic imaging strategy based on the deployment of spatially sparse surface seismic arrays, integrated with a dense baseline array. This will allow users to increase the temporal resolution of the CO2 monitoring. The system will include an accurate reservoir modeling package, which will account for geomechanical and geochemical processes.

This four-year project — performed by faculty and researchers from the University of Miami’s Rosenstiel School of Marine and Atmospheric Science and the University of South Florida, assisted by UNAVCO, Inc., a non-profit consortium funded by the National Science Foundation — aims to develop an integrated, low-cost methodology for assessing the fate of CO2 injected into various classes of geologic reservoirs. The project team will integrate data from space geodesy (which utilizes high precision Global Positioning System [GPS] and Interfero-metric Synthetic Aperture Radar [InSAR] technology to measure subtle surface displacements), seismology, and geochemistry in a straightforward series of procedures and algorithms, and assess the cost and efficacy of these procedures for long-term tracking of CO2. This new approach will be tested at a large-scale CO2 injection test site. Results are expected to confirm suitability of this methodology for most carbon storage sites.

This project will further develop a novel silica molecular sieve membrane for the pre-combustion capture of carbon dioxide (CO2) from coal-based integrated gasification combined cycle (IGCC) power plants. These membranes have the potential to contribute to carbon capture by high temperature separation of hydrogen (H2) from CO2 and other gases present in shifted synthesis gas (syngas). Extensive efforts over the last several decades have explored high temperature H2-selective membranes made of silicon dioxide (SiO2), other oxides, palladium (Pd), and other metals or alloys, polymers, and various zeolites and non-aluminosilicate molecular sieves. Although promising separation results have been reported for many of these technologies, they all suffer from high processing costs for membrane fabrication and/or long term stability limitations. This project will bring a new, simple concept for the fabrication of ultra-thin and stable H2-selective membranes closer to commercial reality.

The objective of the project is to develop an economically-viable H2/CO2 separation membrane system that would allow efficient capture of CO2 at high temperature and pressure from gasified coal in presence of typical contaminants. The key hurdle for commercialization of palladium-based hydrogen separation membranes has been the negative effects of H2S and carbon on hydrogen flux, i.e. membrane poisoning. To date, most membrane developers have used only a few binary alloy systems such as Pd-Cu and Pd-Ag with only recent attempts to employ ternary alloys. Although promising, none has been shown to be an effective deterrent to the membrane damage induced by coal gas contaminants. In addition, new membrane development has been slow with almost no testing being done in actual coal gas environments. Pall will utilize combinatorial material design for high-throughput, rapid screening of a large number of ternary Pd-alloys with the goal of developing an optimized palladium alloy that is tolerant to contaminants while retaining the necessary high hydrogen flux and selectivity characteristics.

Direct Methanol Fuel Cell (DMFC) anode flow-fields are evolved from hydrogen fuel cell flow-fields, and thus not optimized for liquid fuel delivery. NuVant System Inc's two-year Congressionally Directed Project will improve the performance of Direct Methanol Fuel Cells (DMFCs) by designing anode flow-fields specifically for the delivery of liquid methanol. A computer model will be developed that utilizes the relevant physical and chemical properties of methanol to model the flow of liquid fuel through the porous graphite plates that compose the anode flow-fields. The model will evaluate various flow-fields and predict their potential for improved performance. Prototypes based on the down-selected flow-fields will be validated in a small DMFC stack.

This project developed two different injection systems for tagging CO2 with carbon 14 (14C) at atmospheric levels (1 part per trillion) and measuring the radioactivity in collected samples. Since 14C decays to the more common 12C isotope at a known rate, the level of radioactivity in the sample determines how much injected CO2 the sample contains. Such tagging of injected CO2 will lead to quantitative monitoring of injected CO2 and make it possible to accurately inventory geologically stored carbon. The systems were tested in the laboratory and at the CarbFix demonstration project in Iceland, where CO2 has been injected into a permeable basalt formation at 1,970 feet in depth. Once the technology is proven, adoption of this system will provide a quantitative methodology to verify the amount of CO2 stored, thereby increasing confidence in geologic storage.

The project couples a reservoir model and geomechanical model to simulate potential cap rock leakage for the CO2 capture and storage demonstration site at City Utilities of Springfield, Mo. Materials and methods for stopping potential leakage through the cap rock will be examined. The approach is designed to be applicable to other CO2 injection sites.

The project objective is to develop and test a new quasi- three-dimensional, multi-scale hydrologic model that will allow the essential features of the CO2-brine-freshwater system to be included at the local (borehole), regional, and basin scales using sharp-interface theory. Environmental and seismic risks associated with large scale CO2 injection into the Mount Simon Formation will be quantified.

Coal-Seq III is a government-industry collaboration to study coal as a potential CO2 storage reservoir. Partners include Oklahoma State University, the Illinois Clean Coal Institute at Southern Illinois University and Higgs-Palmer Technologies. The project focused on the development and testing of three advanced geochemical and geomechanical simulation modules which increase the accuracy of simulating CO2 behavior in coals and shales. These modules address coal storage factors such as coal failure and permeability enhancement, matrix swelling and shrinking, and competition with water as an adsorbed phase on coals. These enhancements provide better means to predict geologic CO2 storage volumes.

This four-year project—performed by Stanford University’s Stanford Rock Physics Laboratory in partnership with ExxonMobil and Ingrain, Inc.—is providing robust methodologies for using seismic data to quantitatively map the movement, presence, and permanence of CO2 relative to its intended storage location. Optimized rock-fluid models incorporate the seismic signatures of (1) saturation scales and free vs. dissolved gas in a CO2-water mixture, (2) pore pressure changes, and (3) CO2-induced chemical changes to the host rock (Figure 1). Work products from this project include an innovative dataset, methodologies, and algorithms for predicting the seismic response of multiphase and reactive fluids in CO2 storage programs. In spite of advanced techniques for geophysical imaging, current methods for interpreting CO2 saturation from seismic data can be fundamentally improved. Until now, Gassmann’s equations, which relate pore fluid compressibility and the rock frame to overall elastic properties, have been the primary tool for interpreting CO2 plumes from time-lapse seismic data. Gassmann’s model is purely mechanical, and is best suited for conditions of single-phase fluid saturation in relatively inert systems. Yet, CO2-rich fluid-rock systems can be chemically reactive, altering the rock frame via dissolution, precipitation, and mineral replacement. Furthermore, CO2 systems are multiphase, with uncertainties in scales of phase mixing in the pore space and solution of one phase in another. Errors from ignoring the physicochemical factors during CO2 injection can affect predicted seismic velocity changes, resulting in compromised estimates of saturation and pressure of CO2-rich fluids.

The South Carolina Research Institute and its partners evaluated the feasibility of carbon storage in the Jurassic/Triassic saline formations of the buried Mesozoic South Georgia Rift (SGR) Basin that extends west-southwest from South Carolina into Georgia. The Jurassic and Triassic saline formations of the SGR have been identified as prospective CO2 storage areas; however, detailed characterization is needed to reduce uncertainties and validate storage potential. The project evaluated two different locations in the SGR Basin, one in South Carolina and one in Georgia. The project team reviewed existing geologic and geophysical data, reprocessed historical seismic data, collected additional seismic data to fill in historical data gaps, drilled and tested a characterization well, and conducted reservoir modeling, risk assessment, and mitigation studies. Seismic and geologic data were also used to evaluate faults, fractures, and confining zone integrity for potential release pathways. The characterization well was drilled to approximately 6,200 feet. The findings include a detailed description of the potential reservoirs and seals to determine thickness, lithology, mineralogy, and fracture orientation.

Application selected from ARRA 2009 DOE FOA Number DE-FOA-0000032, entitled "Recovery Act: Geologic Sequestration Training and Research". The primary objectives of this project are to develop a methodology for the geological and geotechnical site characterization in mafic rocks through both simulations and field work and completing an economic analysis of these opportunities. This project will support graduate and undergraduate students.

Application selected from ARRA 2009 DOE FOA Number DE-FOA-0000032, entitled "Recovery Act: Geologic Sequestration Training and Research". The objective of this project is to integrate ongoing research on CO2 separation from coal combustion flue gases using regenerable magnesium solutions with engineering education in CCS for chemical and environmental engineering students. This project will support graduate and undergraduate students.

This project characterized the Pliocene and Miocene sediments in the Wilmington Graben, offshore of Los Angeles, CA, for CO2 storage. Characterization of these formations will help establish and broaden options for large-scale CO2 geologic storage throughout California. The project was performed in three phases, with the first phase devoted to completing a detailed review and interpretation of existing exploration well log data, 2-D and 3-D seismic data, acquiring and analyzing new seismic lines in current data gap areas, reviewing existing log data, and drilling a Pliocene well in northern Wilmington Graben area. In the second phase of the project, a second characterization well was drilled into the Miocene. Integrated 3-D geologic and geomechanical models for the Wilmington Graben were populated with grid data derived from lithologic properties to allow for additional quantification and analysis of storage targets and seals. A CO2 injection and migration model was also developed and calibrated against well injectivity data to simulate long-term injection, CO2 migration, and storage. In the third phase of the project, a detailed engineering review and documentation of the top 20 CO2 emission sources in the LA Basin was performed, and a feasibility analysis using existing and/or new pipelines in the LA Basin to transport CO2 from sources to storage sites was completed.

Application selected from ARRA 2009 DOE FOA Number DE-FOA-0000032, entitled "Recovery Act: Geologic Sequestration Training and Research". The objective of this project is to use "carbonsheds," a concept that was developed as a framework for optimizing transport of CO2 on an integrated technical, economic, societal and environmental basis. This project will support two graduate students.

Application selected from ARRA 2009 DOE FOA Number DE-FOA-0000032, entitled "Recovery Act: Geologic Sequestration Training and Research". Project objectives include: 1) Develop a CCS short course introducing suite of technologies and deployment issues; 2) Establish a CO2 capture laboratory for data analysis and develop mathematical models; 3) Offer internships; and 4) Establish the Tuskegee CCS Network.

NETL, in partnership with the Environmental Outreach and Stewardship (EOS) Alliance, Pacific Northwest National Laboratory (PNNL), has developed a regional carbon storage technology training center to deliver CCUS technology training and information to stakeholders in the Pacific Northwest. This training center provides a platform for geologic CO2 storage related technology information, establishing an advisory board, offering a suite of revenue-generating training classes, and implementing a marketing strategy for prospective students with the goal of the center to become self-sustaining within three years. EOS Alliance and partners have developed short courses on various aspects of CCUS technology. Instructors for these courses come from PNNL, academia, industry, and other national laboratories. The course offerings focus on technologies (Figure 1) and issues relating to the U.S. Pacific Northwest region, and include lectures on CCUS technologies, several multiple-day combined courses that integrate technical topics, and tours of facilities conducting cutting edge geologic CO2 storage research. EOS Alliance is working to register the CCUS courses for Professional Development Units (PDUs) and is evaluating the feasibility of establishing a certification program. EOS Alliance will take the lead in planning and managing this program. In partnership with PNNL and the EOS Alliance will coordinate and monitor the regional CCUS training project performance, maintain sufficient project management staff, support the Advisory Board, implement strategic planning, work with other regional carbon storage technology training recipients, create and provide all deliverables to DOE, and maintain appropriate fiscal and accounting systems. Additional information can be found at http://www.carbontechalliance.org/

The Illinois State Geological Survey (ISGS) conducted an evaluation of the carbon storage potential of the Cambro-Ordovician Strata of the Illinois and Michigan Basins, which underlie much of the states of Illinois, Indiana, Kentucky, and Michigan. Whole core of the Knox and Maquoketa Shale were taken from several wells drilled for the Midwest Geological Sequestration Consortium field test and the Industrial Carbon Capture and Storage demonstration project in Decatur, Illinois. Additionally, 120 miles of 2-D seismic data were acquired in western Illinois to enhance the characterization of the Illinois Basin. A small-volume carbon dioxide (CO2) injection test was also conducted in Hancock County, Kentucky to evaluate the injectivity of the Knox. These data and other available data were used to estimate the regional injectivity and storage capacity of the Knox Super Group and the St. Peter Sandstone. Specific studies included modeling the dissolution of CO2 in brine and the interaction with carbonate reservoir rocks, geomechanical tests and petrophysical analyses, an evaluation of mineralization rates, and an analysis of seal faulting potential.

New Mexico Institute of Mining and Technology, in partnership with Texas A&M University and the University of Utah, developed a regional carbon storage technology training center for the southwestern United States (CO2TC). The purpose of this training center was to increase the CCS workforce though the development and implementation of academic programs, specialized classes, continuing education, professional development, and public awareness.

The project built on current outreach and education programs to recruit and prepare students in the region for careers related to the geologic storage of CO2. Students were engaged at all educational levels, from K-12 to generate early interest, to secondary education students by providing their teachers with classroom tools and training, to college students from several disciplines that cover all aspects of the CCS industry (i.e., MBA programs, law, computer science, humanities, social & behavioral science, etc.). The training center also conducted outreach and continuous updated training courses for current professionals inclusive of industry, non-governmental organizations, the general public, and the media to provide greater awareness of the importance of geologic carbon storage.

 

NETL partnered with the Southern States Energy Board (SSEB) and others from both industry and academia to develop the Southeast Regional CO2 Sequestration Training Program (SECARB-Ed) for the southern United States. These partners have established a CCS regional training program to facilitate national and global deployment of CCS technology. The project performed a series of tasks over a three-year period. Major project tasks included: Initiating and implementing a Sponsorship Development Program that allows SECARB-Ed to be self-sustaining after the initial three-year period by establishing an advisory board, developing a strategy for revenue generation, and marketing. Establishing a CCS technology curriculum by identifying topics for short courses, positioning SECARB-Ed to take advantage of opportunities to showcase its capabilities, and seeking technical societies’ approval of the training materials. Facilitating technology transfer through the utilization of electronic and printed media. Supporting research and outreach/education goals of the Southeast Regional Carbon Sequestration Partnership (SECARB). Additional information on SECARB-Ed can be found at http://www.secarb-ed.org/

CO2 Saline Storage Demonstration in Colorado Sedimentary Basins addresses applications-oriented issues in reservoir assessment and dynamic processes affecting injection operations. The focus is on geomechanics, mineral dissolution, geomicrobiology, and pore space related to storage of large volumes of CO2 in saline brine aquifers. Project activities are directed toward studies that will guide future industrial CO2 saline storage operations in Colorado.

The University of Alabama, Geological Survey of Alabama, and Rice University have assessed the CO2 storage potential in the Black Warrior Basin. Roughly 28 million metric tons of CO2 are released into the atmosphere annually by two pulverized coal power plants located in the basin, providing a need to determine the geological storage resources for potential CCS in the Black Warrior Basin. The project team has characterized a test site located near one of those power plants, the Alabama Power Company William C. Gorgas plant. The effort included designing and developing a geologic test wellbore, determining the suitability of the site for storage, and performing a computational simulation of the reservoir. As part of the characterization activities, the team is evaluating a formation stratigraphic, dissolution, and mineralization containment analysis that defines the ability of the formation to contain CO2. The project team also analyzed geophysical well logs, seismic surveys, and core data to define the CO2 acceptance and storage capability of the stacked saline reservoirs.

NETL is partnering with the University of Miami to provide educational training by assisting in the development of an integrated, low cost methodology for assessing the fate of CO2 pumped into various classes of geologic reservoirs. Project participants will assist in integrating geodetic, seismological, and geochemical data by using Interferometric Synthetic Aperture Radar (InSAR) data to construct inter-ferograms (photographic records of optical interference phenomena) at several of the DOE’s Regional Carbon Sequestration Partnership (RCSP) Validation Pha+E472:E474se II “legacy” sites and RCSP Deployment Phase III sites. This technology will provide a gross characterization of upper crustal response for sequestration activities under a variety of conditions. Assessments of the geochemical environments in the sites, and the potential for more detailed geochemical modeling, will be completed and integrated with the geodetic studies.

This project trains students on theoretical rock physics models that can predict the changes in the mineral framework of porous rock based on geological and geochemical conditions and the resulting changes in its porosity; elastic properties; absolute and relative permeability; and electrical formation factor. These results help in quantifying seismic and electrical data for monitoring geologic CO2 sequestration.

The objective of this project is to develop an efficient and low-cost CO2 capture solid sorbent which is highly resistant to SO2 poisoning and thermal degradation. The proposed concept is built on integration of acid-base chemistry with a novel approach for manipulating basic site distributions. This project will support at least 2 graduate students during the research effort.

The project will support at least 2 graduate students while examining the nature and controls of caprock integrity on CO2 sequestration systems by studying exhumed analogs where modern and ancient CO2 flow has occurred. The team will evaluate the nature of fracture systems and faults and examine the nature of mineralization within some of these exposures.

The project team will conduct research to assess the migration of CO2 in a geologic formation in Missouri, conduct reservoir modeling, and develop a GIS database of pore-fluid chemistry within and above potential CO2 injection zones in Missouri. This project will support at least two graduate students during the research effort.

The project team will develop a series of advanced oxygen carriers for coal-fueled chemical looping combustion (CLC) to yield a high purity CO2. A CLC process model will be built to optimize the performance of the selected oxygen carriers. This project will support at least two graduate students during the research effort.

The Cretaceous Dakota Sandstone, Jurassic Entrada Sandstone, and the Pennsylvanian Weber Sandstone are very promising geologic storage formations in the Rocky Mountain Region. These formations are ubiquitous throughout the region and represent common geologic storage candidate sites for most point sources in the region. This project is focusing on collecting and analyzing rock core and geophysical data from these formations as well as conducting new data collection and model simulation analyses for a representative case-study area near the Craig Power Station in northwestern Colorado. This includes analysis of the storage potential of these deep-saline formations within a large, Laramide-age structure just south of the town of Craig, Colorado. A detailed structural analysis of this large forced fold was performed; in addition, the finer geologic structure and stratigraphy of the candidate saline aquifers and their overlying seals was characterized. Analyses of the broader region include the Navajo and other promising Jurassic-aged storage target formations. In addition, project researchers are characterizing the local and regional storage potential of these most promising formations using fundamental geological, geophysical, and existing rock core data from all areas of the region.

The project objective is development of a 1 x 4 fiber optic sensor array for sub-surface carbon dioxide (CO2) detection. The proposed fiber sensor array is a low cost, reconfigurable sensor that has the potential for large area coverage based on the number of fiber probes that can be accessed using one laser and two photo-detectors in the call/receive geometry.

The University of Texas at Austin's Bureau of Economic Geology (BEG) is partnering with Battelle's Pacific Northwest National Laboratory, AOA Geophysical, Global Geophysical, Geokinetics, Ascend Geo, Austin Powder, Seismic Source, and RARE Technology to combine multicomponent seismic technology and rock physics modeling that will lead to more accurate monitoring, verifying, and accounting (MVA) of stored CO2. The research will use conventional seismic sources and data-acquisition systems and also new seismic sources that emphasize shear waves and new seismic data-acquisition technology based on cableless data recording to acquire seismic research data across one or more brine-formation systems appropriate for CO2 storage. Research tasks will involve acquiring, processing, and interpreting both conventional seismic data and multicomponent seismic data. Scientists at PNNL and BEG will analyze well logs, cores, and reservoir test data to construct geological models of CO2 storage formations and seal units across each study site. By combining P-wave and S-wave seismic attributes with appropriate rock physics models, the research team will show how multicomponent seismic technology allows definition of formation storage compartments, detection of leaky seals, mapping of fluid-flow paths, segregation of high and low gas saturations, and quantification of intra-reservoir permeability barriers that cannot be achieved with conventional single-component seismic data.

This project provides a basis for providing graduate and undergraduate students the opportunity to participate in research related to the modeling of fluid-driven fractures. The research approach will include numerical analyses with the discrete element and boundary element methods, and physical experiments for material estimation and model testing.

NETL has partnered with Brooklyn College to determine the role of textural (e.g., the pore-throat size; distribution, geometry, and sorting; grain size; degree of bioturbation; specific surface area; preferred orientation of matrix clay minerals; and orientation and aspect ratio of organic particles) and compositional parameters (e.g., silt content; ductility; compaction; mineralogical content; proportion of soft, deformable mineral grains to rigid grains; cementation; organic matter content; carbonate content; and ash content) that control the CO2 sealing capacity of caprock formations. Caprocks are low-permeability rocks that comprise confining zones located above the CO2 injection zone and can act as a seal to prevent the upward migration of CO2 into other formations. The research is also serving as scientific training for at least one graduate student and one undergraduate student. The students are collecting samples, searching scientific literature, performing most lab measurements, writing scientific dissertations, and participating in disseminating project results through publications and by attending scientific meetings.

NETL has partnered with the Massachusetts Institute of Technology (MIT) to develop tools to better understand and model CO2 storage permanence in geologic formations at the geologic basin scale. This research contributes to deploying CCUS at a gigatonne per year injection scale over the course of several decades. Continuous CO2 injection of this magnitude must be understood at the geologic basin scale. The project is performing fundamental research on CO2 migration, fate, and displaced brine at the geologic basin scale. Additionally, MIT is developing analytical sharp-interface models of the evolution of CO2 plumes over the duration of injection (decades) and after injection (centuries). MIT has experience in investigating closed-form analytical solutions that account for plume shape during CO2 injection and for regional groundwater flow. From accomplishments obtained in this past research, MIT extended the modeling use in this project to include the essential physics governing plume migration: (1) induced pressure gradients, (2) capillary trapping, (3) buoyancy, (4) regional groundwater flow, (5) aquifer slope, (6) dissolution into the brine (due to both diffusion from residual CO2 and convective mixing from mobile CO2), and (7) loss through the confining unit (Figure 1). MIT applied the analytical solutions of CO2 plume migration and pressure evolution to specific geologic basins to estimate the maximum footprint of the plume, and the maximum injection rate that can be sustained during a given injection period without fracturing caprock. These results have led to more accurate resource estimates, based on fluid flow dynamics, rather than ad hoc assumptions of an overall “efficiency factor” typically used in storage capacity estimation calculations. In addition, MIT used risk assessment methodologies to evaluate the uncertainty in their predictions of storage capacity and leakage rates. The results of the research were incorporated into the short course titled “Carbon Capture and Storage: Science, Technology, and Policy” offered through the MIT Professional Institute to train the present and future CCS workforce.

This project focuses on the use of seismic data for assessing CO2 storage reservoirs. The project will train students on numerical simulation of advanced seismic data ideal for mapping of caprock integrity and potential leakage pathways. The project will use numerical simulation to test rapid methods of gathering multi-component, full azimuth data ideal for this purpose.

Researchers at the Colorado School of Mines have developed a comprehensive simulation tool for analyzing and modeling the coupled physical, chemical, thermal, and geomechanical processes involved in CO2 flow, storage, migration, and mineralization during long-term geologic carbon storage in saline aquifers. The simulator models the complex geology of these formations, including heterogeneity, anisotropy, fractures, and faults. The simulator also models geochemical and geomechanical processes that would occur during geologic storage of CO2. It uses parallel computation methods to allow rapid and efficient modeling assessment of CO2 injection strategies and long-term prediction of geologic storage system behavior and safety. Small-scale test experiments were used to identify the fundamental processes in homogeneous systems and test the ability of the macroscopic-scale models to capture the capillary and dissolution trapping processes in the presence of pore-scale heterogeneities. Overall, the model simulations support the evaluation of geologic storage mechanisms as a viable technique for reducing atmospheric CO2 emissions.

The University of Texas at Austin and its partners at Los Alamos National Laboratory (LANL), Environmental Defense Fund, and Sandia Technologies, LLC have investigated Texas offshore subsurface storage resources in the Gulf of Mexico as candidate geologic storage formations. This project was designed to identify one or more CO2 injection site(s) within an area of Texas offshore state lands (extending approximately 10 miles from the shoreline) that are suitable for the safe and permanent storage of CO2 from future large-scale commercial CCS operations. The approach used in identifying these injection sites was to use both historic and new data to evaluate the candidate geologic formations, including an extensive Gulf Coast well database and seismic survey database. A major project effort was to characterize three selected offshore areas with high-resolution seismic surveys that were conducted by the project. In addition, reservoir simulations were performed and work was conducted to evaluate the effects of chemical reactions resulting from injection of CO2 into the identified formations. A risk analysis and mitigation plan has been generated in support of near-term commercial development efforts.

Create modules for undergraduate and graduate students. Data & presentations from industry CO2 Flooding Schools & Conferences, Carbon Mgt Workshops & other venues will be tailored to provide introductory reservoir & aquifer training, state-of-the-art methodologies, field seminars, site visits, and case studies for students. This project will support Graduate students during the research effort.

NETL has partnered with the West Virginia University (WVU) to conduct a three-year study of the Citronelle field located in Mobile County, Alabama, to determine the diagenetic (physical, chemical, and biological) alteration of reservoir rock and formation fluid properties due to injection of supercritical CO2 into mature, conventional hydrocarbon reservoirs. The study is using comprehensive geochemical assessments of core and formation fluid from the Citronelle field to test a reactive transport model for prediction of supercritical CO2-fluid-rock interactions. This modeling can be used to predict dissolution and/or mineral trapping in the reservoir rock and guide engineering, assessment of storage capacity, development, and monitoring of CO2 storage sites.

The Citronelle oil field (Figure 1) is an ideal site for CO2 storage because of its geology and the pre-existing CO2 infrastructure in the region. The Citronelle field is currently the focus of an on-going CO2-enhanced oil recovery (EOR) project led by the University of Alabama and NETL. CO2-EOR has been viewed as the most promising near term approach for CO2 storage, due to the economic return from extracted oil. Thus, this study is highly relevant to emerging technologies. Also, a state-of-the-art geologic model of the Rodessa Formation reservoir, a major oil and gas reservoir in the eastern Mississippi Interior Salt Basin and promising EOR target, has been created as aresult of the on-going CO2-EOR DOE project.

 

NETL, in partnership with the University of Texas at Austin, has developed the Alliance for Sequestration Training, Outreach, Research and Education (STORE), which is a regional carbon storage technology training center for the Gulf Coast states that facilitates national and global development and deployment of CCUS technology. The training center accomplishes this through technology transfer events; webinars; student, professional, and public training courses; seminars; and communication through newsletters, email tech alerts, and a website. This training makes a vital contribution to the scientific, technical, and institutional knowledge needed to develop commercial CCUS projects. By providing educational and training programs necessary to produce a skilled professional CCUS workforce, the University of Texas at Austin helps the nation meet the need to capture and store large amounts of CO2. In addition, the center promotes transfer of regional CCUS technology expertise, provide the public, CCUS industry and other interested parties with a variety of professional services, and works with all stakeholders to advance CCUS from demonstration stage to deployment.

This project will develop a process based risk assessment model to determine quantitatively the potential risks and impacts of CO2 storage, as well as cost savings for risk mitigation. The model will be applied to the SACROC field site in Texas and two other known CO2 geologic storage sites.

This project, in Seattle, shall develop an integrated system-level risk analysis approach for geologic CO2 storage by adapting and extending an existing highly regarded and widely used probabilistic simulation framework (GoldSim) that was originally developed for long-term safety analyses of nuclear waste disposal.

Application selected from ARRA 2009 DOE FOA Number DE-FOA-0000032, entitled "Recovery Act: Geologic Sequestration Training and Research". Project addresses the need to measure the Dissolved Inorganic Carbons in underground brine water at higher sensitivity, lower cost, in situ, at higher frequency and over long periods of time for CO2 sequestration MVA. This project will support at least 2 graduate students.

The primary objective of the proposal is to provide training opportunities for graduate students in the development and validation of an advanced three-dimensional simulation and risk assessment model that can be used to predict the fate, movement and storage of CO2 in underground formations, and to evaluate the risk of their potential leakage to the atmosphere and underground aquifers.

The primary objective is to train graduate and undergraduate students and advance the science in two critical areas of risk assessment (1) multi-process, multi-scale characterization and model simulation of the risks associated with leakage into overlying aquifers and (2) pore-scale geochemical processes in CO2 sequestration related to injectivity and storage including mineral reactivity and multiphase fluid reactions, needed to assess the likelihood of an successful sequestration effort.

This project offers training opportunities for graduate and undergraduate students who are conducting research on the effects of CO2 leakage on multiple drinking water aquifers. Duke University is conducting long-term incubations and chemical simulations using aquifer sediments from many locations in order to present a risk assessment that is as accurate and as comprehensive as possible to prioritize areas with the greatest risks for geosequestration and to highlight areas where such risks are low.

Through its core research and development program administered by the National Energy Technology Laboratory (NETL), the U.S. Department of Energy (DOE) emphasizes monitoring, verification, and accounting (MVA), as well as computer simulation, of possible carbon dioxide (CO2) leakage at CO2 sequestration sites, along with risk assessment of those sites. MVA efforts focus on the development and deployment of technologies that can provide an accurate account of stored CO2, with a high level of confidence that the CO2 will remain permanently sequestered. Effective application of these MVA technologies will ensure the safety of sequestration projects with respect to both human health and the environment, and provide the basis for establishing carbon credit trading markets for sequestered CO2. Risk assessment research focuses on identifying and quantifying potential risks to humans and the environment associated with CO2 sequestration, and helping to ensure that these risks remain low.

The University of Kansas (KU), BEREXO Inc., Bittersweet Energy Inc., Kansas Geological Survey, and the Kansas State University evaluated potential CO2 storage sites, including saline aquifers and depleted oil reservoirs, within the Ozark Plateau Aquifer System (OPAS) in south-central Kansas. The study focused on the Wellington Field, with an evaluation of the CO2-enhanced oil recovery (EOR) potential of its Mississippian chert reservoir and the storage potential in the underlying Cambro-Ordovician Arbuckle Group saline reservoir. A larger study of the saline reservoir was undertaken over a 33 county area in south-central Kansas to evaluate regional CO2 storage potential. Additionally, the EOR potential of the Chester and Marrow Sandstone reservoirs is being evaluated. This study integrated well data, seismic, geologic, and engineering approaches to evaluate CO2 storage potential. The project estimated the CO2 storage potential of multiple formations by constructing integrated geological models followed by reservoir simulation studies. The effort collected available data, drilled and logged three new wells through the Arbuckle Group, cored a portion of the injection and confining zones, and performed chemical and physical analyses on the samples. Analysis of the geochemistry of formation fluids was conducted, and a simulation of fluid flow and geochemical interactions was performed.

This project has identified leaky wellbores as an important risk to storage integrity that warrants further study to develop methods to quantify the risk of CO2 release through active and abandoned wellbores. It has developed a new method to relate the risk of release through existing wells at geologic carbon storage sites to data collected by non-destructive cement mapping tools. The data from wellbore logging tools were employed to develop models for leakage risk in wells. Methods to quantify the probability of leakage were developed for the casing, cement, cement-casing interface, cement-formation interface, and any existing defects. Models for risk of release through wells can then be developed that use collected data to establish the overall probability of leakage of a given well. Information obtained from well logging can be input into a model to evaluate the probability of leakage for specific zones in the well, e.g., the casing, cement, cement casing interface, cement-formation interface, and any existing defects.

The main objective of this proposal is to properly train graduate students to develop multi-scale Finite Element (FE) models of different geological settings and compare the results concerning geomechanical processes, such as how fluid pressure induces rock deformation, how faults and fractures affect fluid migration, as well as critical wellbore placement and wellbore integrity to each other. This shall give a more thorough understanding of how reservoir geometry affects wellbore stability, formation and cap rock stability and thus shall facilitate future site selection.

NETL has partnered with Purdue University to conduct training and research to determine the depositional and diagenetic characteristics of CO2 storage and caprock formations; the low-permeability formations located above the CO2 injection zone(s) that prevent the upward migration of CO2. Depositional characteristics help to determine where sediment was deposited and lithified, such as a beach, lake, or dune. Diagenetic characteristics, such as compaction and cementation, illustrate the physical, chemical, and biological changes that take place in sediments as they become consolidated into rocks. This project also explored methods for predicting changes in the mineralogy (chemical composition) and texture that occur when rocks are exposed to CO2-saturated brines. During the project, graduate students conducted original scientific research into topics related to the lithological, textural, and compositional variability in formations that were analyzed as possible CO2 storage reservoirs and seals. The students focused primarily on analyzing core samples and geophysical well-logs of the Mount Simon Sandstone (Figure 1) and overlying E au Claire Formation seal.

NETL, in partnership with the Petroleum Technology Transfer Council (PTTC), the American Association of Petroleum Geologists, and the Applied Petroleum Technology Academy has developed a regional sequestration technology training center to deliver CCUS technology training and information to stakeholders in the Permian Basin Region of western Texas and southeastern New Mexico through an established technology transfer network, online capabilities, and a communications program. The Permian Basin is an ideal target for this type of training since is it a major oil and gas producing region, contains oil fields that show promise for CO2-enhanced oil recovery (EOR) and carbon storage activities, and has an extensive CO2-EOR infrastructure already located throughout the region. To implement this project, PTTC has created courses and lecture materials for academia and industry related to CCUS and conduct annual training events geared toward universities and colleges. PTTC is utilizing multiple approaches to deliver its technology transfer and training programs, including regional workshops, presentations at technical meetings, a focused research-oriented workshop, an online certificate program, webinars/e-symposia, and communication through newsletters, email tech alerts, and a website located at http://www.permianbasinccs.org/.

The objective of this project is to create a web-based simulator with comprehensive chemical and physical processes relevant for modeling CO2 sequestration systems and then to use this simulator as part of a course on CO2 sequestration and modeling. The simulator is intended to evaluate the effect of injected CO2 on the target rocks and the resulting chemical changes and how this shall affect flow and heat transfer. This project shall also provide an opportunity at San Diego State University to further develop existing industry-supported multidisciplinary applied computational sciences programs and well trained personnel for the industry.

This project shall establish data collection and processing requirements so that double-difference seismic tomography can be used to quantitatively map the mass and propagation of sequestered CO2 as a function of time. Additionally, a dataset from field monitoring of microseismic activity shall be analyzed using double-difference tomography. Finally, a graduate course shall be developed to enable students to apply the best, most recent methods for using geophysical tools to image sequestration.

Sandia Technologies, LLC (Sandia), in partnership with Conrad Geoscience Corporation, Schlumberger Carbon Services, Columbia University, Rutgers University, the New York State Museum, and the Lawrence Berkeley National Laboratory, examined the potential for large-scale, permanent storage of CO2 in deep strata of the Newark Rift Basin (NRB). The NRB underlies a heavily industrialized region comprising parts of New York, New Jersey, and Pennsylvania. The primary focus of this project was to examine and prove the suitability of these Triassic to Cambrian formations for geologic storage of CO2. The project included the analysis of existing hydrologic, geologic, and oil and gas well data; development of a Geographic Information System (GIS) database; geologic and conceptual modeling; and drilling and completing a characterization well. Drilling a stratigraphic test well to near-geologic basement (approximately 8,000 feet total depth) provided Sandia with formation water samples, native formation pressures, and estimates of formation porosity, permeability, grain and bulk density, lithology, and mineralogy. A second characterization well was drilled in conjunction with Columbia University, and a 2-D seismic survey was completed to further characterize the basin.

The goal of this project is to experimentally quantify rapid CO2 capture and storage (CCS) rates via mineral carbonation in peridotitic and basaltic rocks, and to test the hypothesis that rapid carbonation of peridotite leads to a positive feedback via "reactive cracking", in which cracks caused by large volume changes enhance porosity, permeability and reactive surface area.

The Recipient shall develop a microbial and chemical enhancement scheme for in-situ carbon mineralization in geologic formations. This system shall consist of thermodynamic and kinetic studies of CO2-mineral-brine systems and shall investigate the influence of organic acids produced by a microbial reactor on in-situ mineral carbonation.

The Recipient shall develop a computational technique which relies upon variational statistics in pore size and pore throat size in order to determine the transport and free-phase storage of carbon dioxide in coal seams.

The project objective is to develop a unique class of multifunctional metal oxide/perovskite based composite nanosensors for industrial and combustion gas detection at high temperature (700oC-1300oC). A miniaturized bi-module sensing platform will be designed and fabricated with a parallel, combinatory, and multiplex array of integrated electro-resistive and electrochemical nanosensors to meet the challenge of high temperature complex gaseous environment in various combustion conditions.

This project will characterize the growth requirements of a biofilm-producing supercritical CO2 (scCO2)-tolerant microbial consortium; evaluate the ability of this consortium to reduce permeability in sandstone under simulated reservoir conditions; investigate the mechanisms of scCO2 tolerance in isolated strains; and analyze the microbial diversity for scCO2 tolerant microbes at CCS sites.

This project aims to develop CO2 sensor and instrument for measuring and monitoring CO2 emissions for geological sequestration sites in a continuous mode, while providing training opportunities to two graduate students in the areas of acoustic wave sensors, nanomaterials and geological sequestration of CO2.

The University of Wyoming and the project partner organizations have characterized the Rock Springs Uplift (RSU) and Moxa Arch deep saline reservoirs in southwestern Wyoming to pave the way for commercial- scale CO2 storage projects within the region. These reservoirs have been characterized by drilling a test well in the RSU, performing extensive testing in and around the well, and processing data from a well in the Moxa Arch that had been installed previously by ExxonMobil. Analytical measurements taken within the wells and from tests performed on samples removed from the wells help to determine the suitability of the reservoirs to store CO2. An additional study has assessed potential release paths from the reservoirs. Specific tasks completed as part of the project included: (1) the installation of a characterization well at the RSU site for the purpose of gathering cores, fluid samples, and geophysical data; (2) 3-dimensional, 3-component seismic surveys and electromagnetic (EM) surveys of the area surrounding the RSU well; (3) development of well catalog and wellbore risk assessments for the RSU and Moxa Arch sites; (4) performance of structural and stratigraphic characterization of the RSU and Moxa Arch sites; (5) analysis of host rock mineralization and its effect on CO2 injectivity and storage and analysis of formation fluids; and (6) design of a commercial-scale sequestration project that includes options for the disposition of displaced waters and a complete performance risk assessment.

The Recipient shall provide a graphical user interface program through which previously developed numerical tests can be interfaced for the purpose of determining the optimum spatial distribution of boreholes for tracking a CO2 plume and displaying the data in a three dimensional format.

In this Recovery Act project Missouri University of Science and Technology (MST) will enhance its existing CCS training and research program by offering courses in CCS topics. Student will attend field trips with "hands-on" involvement and conduct research on potential sequestration targets in the Midwest.

In this Recovery Act project the University of Illinois Urbana-Champaign (UIUC), in collaboration with the UIUC Department of Geology, Institute of Genomic Biology and the Midwest Geological Sequestration Consortium, will provide training and research opportunities for students who will participate in a study to evaluate the subsurface microorganism response to injected CO2 at the ADM Sequestration Site in Decatur, Ill.

NETL is partnering with Southern Illinois University (SIU) to undertake a comprehensive study to understand the potential interactions between organic rocks and CO2. Interactions between various ranked coals (lignite, sub-bituminous, bituminous, and anthracite) or organic shale with CO2 are complex and not well understood.

The fact that potential risks associated with their storage are seldom evaluated under plausible but extreme transient conditions poses a concern. Most risk assessments are typically accomplished under equilibrium conditions. However, under extreme non-equilibrium conditions (whether natural, seismic, or manmade) there are potential situations that could lead to the re-emission of CO2 stored in organic rocks. The possible interactions have not yet been studied in detail. In addition, SIU is attempting to evaluate how potential pressure and temperature variations, typically encountered under natural seismic conditions, can control the emission, adsorption, and absorption behavior of stored CO2.

 

The Recipient shall perform a combined experimental and modeling study of air capture of CO2 using low-cost, high-capacity sorbents such as hyperbranched amino-polymers. In addition, the Recipient shall examine the adsorption/desorption cycles for approaches using only diurnal temperature variations as energy input, as well as approaches where additional energy input from solar thermal sources is considered.

NETL, in partnership with the Illinois State Geological Survey (ISGS) and the Midwest Geologic Sequestration Consortium (MGSC), has developed the MGSC Sequestration Training and Education Program (STEP) to disseminate CCUS technology and provide education and training opportunities for engineers, geologists, service providers, regulators, executives, and other CCUS personnel working within the Illinois Basin region of the United States.

Princeton investigators will develop a framework for examining carbon capture and storage investment decisions in light of uncertainty in CO2 leakage risks, potential subsurface liability, and the associated losses in carbon credits. The project team seeks to develop a framework to quantify leakage risk in probalistic terms, and combine it with a basin-scale model of competing subsurface land uses.

The University of Akron will demonstrate the technical and economic feasibility of building a 250 kilowatt (kW) direct-coal fuel cell (DCFC) pilot plant. Researchers at the University of Akron (UA) have demonstrated the technical feasibility of a laboratory coal fuel cell that can economically convert high sulfur coal into electricity with near-zero negative environmental impact. Scaling up this coal fuel cell technology requires two key elements: developing the manufacturing technology for the components of the coal-based fuel cell; and long-term testing of a kW-scale fuel cell pilot plant. This novel coal fuel cell technology is expected to be a highly efficient, super clean, multi-use electric generation technology which promises to provide low cost electricity by expanding the utilization of U.S. coal supplies and relieving our dependence on foreign oil. A DCFC stack consists of multiple fuel cells which are interconnected electrically. The performance of the stack will be simulated on the basis of preliminary design and the single cell performance. The simulations and test data will be used to further refine the design.

Air Products has designed, constructed and is operating a state-of-the-art system to capture the CO2 emitted from two large steam methane reformers. The reformers are located in Port Arthur, Texas and used by Air Products for large-scale hydrogen production. The CO2 removal units utilize Vacuum Swing Adsorption (VSA). Air Products is working with Denbury Resources, Inc. to transport the captured gas via pipeline to oil fields in eastern Texas where it is used for Enhanced Oil Recovery and thereby sequestered.

The objective of the proposed project is to model, fabricate, and test thin film amorphous alloy membranes which separate hydrogen from a coal-based system with performance meeting the DOE 2015 targets of flux, selectivity, cost and chemical and mechanical robustness, without the use of PGMs (platinum group metals). This project will use a combination of theoretical modeling, advanced physical vapor deposition fabricating, and laboratory and gasifier testing to develop amorphous alloy membranes that have the potential to meet all DOE targets in testing strategies outlined in the NETL Membrane Test Protocol.

This project will demonstrate the capability of the GE Posimetric® pump for use in dry-feeding mixtures of coal and biomass into a pressurized entrained-flow gasifier. Various coal and biomass types will be mixed in a variety of ratios. Properties of the mixtures such as compressibility, friction factor, and gas permeability will be tested to obtain specifications for biomass pretreatment for gasification. Mixtures that meet specifications will be used to test the capability of the Posimetric pump on a demonstration scale and an economic analysis will be performed.

The objective of this project is to demonstrate an integrated system of industrial CO₂ capture and geological storage in a deep sandstone formation. The project uses CO₂ produced by ADM as a by-product of the production of fuel-grade ethanol. ADM has been capturing CO₂ using dehydration and compression and sequestering it in the Mt. Simon Sandstone formation (saline reservoir). The ethanol plant and the sequestration site are both located in Decatur, Illinois. The project team members include ADM, Illinois State Geological Survey, Schlumberger Carbon Services, and Richland Community College.

This is the first geologic storage project to operate with the U.S. Environmental Protection Agency's (EPA) Class VI injection well permit. This project is demonstrating cutting-edge technologies for intelligent monitoring in the deep verification well (i.e., Schlumberger's IntelliZone compact modular multi-zonal management system-first installation in North America), a downhole seismic monitoring system (i.e., Sercel SlimWave acquisition unit with WAVELAB surface control) in the geophysical well, and Schlumberger's WellWatcher monitoring system that integrates advanced downhole measurement technology with surface acquisition and data communication systems.

The primary objective of this project is to further develop the research efforts previously initiated with the construction and operation of the Hydrogen Research, Development, Test, and Evaluation (RDT&E) facility located at the Yeager Airport in Charleston, WV. The facility generates, stores, and dispenses hydrogen for use in vehicles and equipment that have been converted or designed to operate on hydrogen as their fuel source. Project objectives include the procurement of a various types of hydrogen-fueled vehicles, the development and execution of educational and outreach activities, testing and evaluation of the use of hydrogen vehicles, and the management of the data collected from vehicle testing.

The Center for Advanced Separation Technologies at the University of Kentucky (CAST-KY) will develop advanced technologies that can be used to exploit domestic energy resources and help developing countries reduce their carbon dioxide (CO2) emissions. In addition, new gas-gas separations technologies to be developed at the Center for Advanced Separations (CAST) will have crosscutting applications for a wide spectrum of the Fossil Energy R&D programs. The objective will be met by conducting both fundamental and applied research at CAST, which is a consortium of five universities. The university members include: University of Kentucky, Virginia Tech, West Virginia University, Montana Tech of University of Montana and University of Utah.

Researchers at the University of Central Florida (UCF) will develop accurate and robust wireless passive high-temperature (>1300 degrees Celsius) microsensors for in situ measurement of temperature and pressure within combustion turbines. This research aims to establish a solid foundation for the development of commercially viable advanced sensor technologies for in-situ real-time monitoring of the operation of power generation systems, thus providing precise operational parameters in real-time for optimal system control for higher efficiency, increased reliability, and improved emissions.

This project will develop and optimize novel, nanoporous, metal carbide membranes using molybdenum (Mo) or tungsten (W) rather than platinum group metals. It will test the use of metal carbides and sulfides to separate hydrogen from high-temperature, high-pressure coal synthesis gas. These surface diffusion composite membranes will provide means to achieve DOE hydrogen separation performance goals. Achieving the goal of producing high purity hydrogen separation membrane systems will bring affordable, environmentally sound hydrogen supplies closer to a reality.

PRLC (Prime Research LC) and the Virginia Tech Antenna Group (VTAG) propose to develop a revolutionary wireless sensor technology capable of operating at extreme temperatures and in highly corrosive environments. The technology will completely eliminate the need for cables connecting to the sensors. In many cases it will avoid having to machine feed-throughs to gain access into plant interiors. The technology is enabled by recent developments in radio frequency identification (RFID), high temperature materials, and frequency selective metamaterials.

The objective of this project is to contribute to the development of materials technology for use in advanced ultra supercritical (AUSC) steam turbines. AUSC power plants will operate with steam temperatures up to 1,400°F and pressures of 5,000 psi resulting in a highly efficient power generation process. Estimated plant efficiency increases are as much as 30% compared to sub critical power plants. Research and development on advanced materials is needed to lead to full-scale demonstration and eventual commercialization for AUSC power plants. A three-year preliminary evaluation under Phase 1 identified a wide spectrum of potential alloys and coatings. Preliminary evaluations of a subset of these promising materials included research on mechanical properties, oxidation resistance, weldability, and suitability of alloys and coatings. This follow-on effort will support in-depth, longer term testing that provides material characterization data that is necessary for the design of a steam turbine that is operable in AUSC conditions.

The Lake Charles CCS Project will accelerate commercialization of large-scale CO2 storage from industrial sources by leveraging synergy between a proposed petcoke to methanol plant (Lake Charles Chemical Project) and one of the largest integrated anthropogenic CO2 capture, transport, and monitored sequestration programs in the U.S. Gulf Coast Region. The Lake Charles CCS Project will promote the expansion of EOR in the Gulf region and supply greater energy security by expanding domestic energy supplies. The compression, pipeline, injection, and monitoring infrastructure will continue to sequester CO2 for many years after the completion of the term of the DOE agreement.

This project developed a comprehensive analysis of programmatic and technical risks associated with CO2 storage in deep brine reservoirs. The study quantified the risks associated with CO2 storage projects by: (1) employing Bayesian inference to evaluate storage risks; (2) utilizing the safety record of the CO2 based enhanced oil recovery industry (CO2-EOR) and pilot storage projects to identify and evaluate potential risks; (3) developing and quantifying the nature of programmatic risks; (4) utilizing diverse, highly qualified expert panels drawn from industry and nongovernmental organizations (NGO) to evaluate changing perceptions of programmatic risks; and (5) assessing the possible consequences to water ecology and energy resources from potential leakage of CO2 from deep brine reservoirs.

This four-year project—performed by Planetary Emissions Management, Inc. (PEM)—is developing a carbon-14 (14C) field-ready analyzer having a sensitivity of approximately 1 ppm of fossil fuel CO2 in ambient air. The primary focus of the application is within the near surface environment covering the project area, however, a gas stream from any component of a geologic carbon storage project or location may be analyzed. The analyzer is based on PEM’s already completed multi-isotopic Global Monitor Platform (GMP) and is being deployed for testing and validation at two reference sites: one where CO2 leaks from natural geologic reservoirs and the other a pilot CO2 injection site.

The objective of this project is to investigate oxy-fuel flame characteristics and assess their impact on the operability of oxy-fuel combustion systems. The individual objectives are to (i) measure fundamental flame characteristics of oxy-fuel combustion, (ii) investigate combustor operability issues of oxy-fuel combustion, and (iii) engage and train students in the multiple facets of the project.

This project seeks to improve power plant efficiency and increase net power output by analyzing potential internal uses for heat produced during compression process of carbon capture. Among the thermal integration opportunities to be analyzed are to (1) regenerate post-combustion CO2 capture solvents, (2) preheat boiler feedwater and (3) predry high-moisture coals prior to pulverizing the coal.

This project will develop coating systems to protect the interior of pipelines and process equipment used in the transport post-combustion flue gases from corrosion and other potential stresses resulting from Supercritical Carbon Dioxide with additional contaminants/constituents. The secondary objectives will be designing and preparing polymers resistant to Supercritical Carbon Dioxide with additional constinents which improve physical properties of such a coating film.

This project will demonstrate an innovative process for capturing and utilizing carbon dioxide (CO2) from a coal-fired industrial source to grow algae in an open-pond configuration. A unique phase change material (PCM) will be used in the open-pond approach to tackle three significant challenges in algae biofuels technology. The PCM is an immiscible liquid that floats on and covers a significant portion of the open-pond surface, reducing water evaporation and providing a near-hermetic seal to prevent introduction of invasive species. The PCM also absorbs infrared solar radiation during the day and releases it at night when the temperature drops. Phase 1 of the project focuses on research and development, conceptual design, permitting, and project management activities to prepare for the second phase. Phase 2will provide construction and two-year operation of a pilot-scale outdoor system that will supply sufficient data to substantiate commercialization efforts. The Department of Energy (DOE) will determine if the Phase II effort will be initiated based on the merits of Phase I results.

This four-year project—performed by Planetary Emissions Management, Inc. (PEM)—is developing a carbon-14 (14C) field-ready analyzer having a sensitivity of approximately 1 ppm of fossil fuel CO2 in ambient air. The primary focus of the application is within the near surface environment covering the project area, however, a gas stream from any component of a geologic carbon storage project or location may be analyzed. The analyzer is based on PEM’s already completed multi-isotopic Global Monitor Platform (GMP) and is being deployed for testing and validation at two reference sites: one where CO2 leaks from natural geologic reservoirs and the other a pilot CO2 injection site.

NETL, in partnership with the University of Wyoming and the Wyoming CCUS Technology Institute (WCTI), has developed a regional sequestration technology training center for Wyoming (Figure 1) and the greater Rocky Mountain region that will establish training programs to facilitate national and global development and deployment of CCUS technology. The WCTI will accomplish this by providing several types of CCUS educational programs, promoting transfer of regional CCUS technology expertise, providing the public, CCUS industry and other interested parties with a variety of professional services, and working with all stakeholders to advance CCUS from demonstration through commercial deployment. These programs will include professional workshops, short-courses focused on specific research and technical topics, online courses, webinars/e-symposia, and communication through newsletters, email tech alerts, and a comprehensive website.

This project will determine whether quantitative measurement techniques for Rn activity and CO2 flux can be applied as a means of assessing caprock integrity, and provide training opportunities for two graduate students and one undergraduate student in geologic and geochemical skills required for implementing and deploying this technology for CO2 Monitoring, Verification, and Accounting (MVA).

NETL partnered with the Georgia Institute of Technology (GT) to explore the consequences of coupled hydro-chemo-thermo-mechanical (HCTM) processes related to the injection of CO2 into the subsurface. This work expanded the results from a previous study on the interactions of groundwater acidification and dissolution of minerals and precipitation on pore-scale processes. The scope of work included general analyses in the governing parameter domain, interfacial properties of water, mineral, CO2 and/or surfactant system, interaction between clay particles and CO2, reactive fluid flow as a result of CO2 dissolution, two-phase flow between immiscible CO2 and formation fluid, CO2 break through and sealing strategies, and CH4-CO2 hydrate replacement and hydro-mechanical implications. The project team explored coupled phenomena, identified different zones in the storage reservoir, and investigated their implications in CO2 geological storage. In particular, the research: (1) Explored spatial patterns in mineral dissolution and precipitation (comprehensive mass balance formulation); (2) experimentally determined the interfacial properties of water, mineral, and CO2 systems, including CO2-water-surfactant mixtures to reduce the CO2-water interfacial tension in view of enhanced sweep efficiency (Figure 1); (3) analyzed the interaction between clay particles and CO2, and the response of sediment layers to the presence of CO2 using specially designed experimental setups and complementary analyses; (4) coupled advective and diffusive mass transport of species, together with mineral dissolution to explore pore changes during advection of CO2-dissolved water along a rock fracture; (5) upscaled results to a porous medium using pore network simulations; (6) measured CO2 breakthrough in highly compacted fine-grained sediments, shale and cement specimens; (7) explored sealing strategies; and (8) experimentally measured CO2-CH4 replacement in hydrate-bearing sediments. Analytical, experimental and numerical results obtained in this study can be used to identify optimal CO2 injection and reservoir-healing strategies to maximize the efficiency of CO2 injection and to attain long-term storage.

The project utilizes undergraduate honors students in independent research on the sealing capacity of geologic formations; development of an advanced undergraduate/graduate level course that includes climate change, and carbon sequestration; support of six graduate students who are developing protocols for assessment of seal layer integrity; and analysis of cap rock samples from geologic formations under consideration for sequestration of CO2.

The objective of this project is to provide training opportunities for graduate students in order to improve the human capital and skills required for implementing and deploying CCS technologies. The graduate students shall develop an integrated simulation-optimization framework that may be used to assess the opportunity of implementing geologic sequestration at any given geological site. This project shall represent the first attempt to apply mathematical optimization to support the planning of geologic sequestration

This project will demonstrate and optimize a process to capture carbon dioxide (CO2) from industrial flue gas streams using in-duct scrubbers and sequester it through alkaline clay mineralization. The process uses the captured CO2 to convert an industrial waste, bauxite residue, into a beneficial soil amendment, carbonated alkaline clay. This process will reduce greenhouse gas emissions and will convert a high-volume, highly caustic waste product from aluminum production into a saleable soil-building product.

Calera Corporation will design, build, and operate a Building Materials Demonstration Plant to convert carbon dioxide (CO2) from power plant flue gas into carbonate mineral building materials for use in the construction industry. This study will develop a plan to scale-up the full carbonate mineralization technology for commercial deployment. Using Carbon Mineralization by Aqueous Precipitation (CMAP) technology, anthropogenic CO2 can be used in an economical and environmentally sound process to create useful products. The demonstration plant will operate in conjunction with an existing power production facility in Moss Landing, CA. The beneficial use products derived from the mineralized CO2 will be tested and optimized to maximize their marketability and value. Producing marketable building materials from carbonate minerals with this technology may reduce the net operating costs of sequestering CO2. In addition, with the addition of an electrochemical portion of the project, the potential exists for the co-production of a range of potentially valuable chemical products.

Novomer, along with its subcontractor, proposes to develop polycarbonates from a petrochemical, carbon dioxide, and a proprietary catalyst system first discovered at Cornell University. The system activates inert Carbon Dioxide, enabling it to react with a commodity petrochemical that results in permanent storage of Carbon Dioxide in new chemical structures which are up to 50% by weight Carbon Dioxide. The Energy Department will provide $2.1 million of the proposed $2.63 million Phase I project cost.

This project integrates unique technologies for algal biomass production, lipid yield enhancement, and lipid extraction with mature technologies to produce beneficial energy products through algal capture of carbon dioxide (CO2) from industrial emissions. Phycal will create an integrated microalgal biorefinery (IBR) pilot project using algal feedstock to create energy products for conversion to fuel for transportation and power generation. Previous DOE programs have shown algal production offers a significant and sustainable domestic potential yield of biomass while sinking large amounts of CO2. Phycal's pilot-scale IBR could lead to commercial production of algal biofuels as early as 2016.

This project will develop a plan for pilot scale evaluation of the SkyMine process to capture carbon dioxide (CO2) from from a cement manufacturing facility flue gas stream and convert the absorbed CO2 through co-production of carbonate and bicarbonate materials. This pilot-scale project will conduct testing of the SkyMine carbon utilization process at a scale sufficiently large to evaluate the technical viability and the economics of process.

The overall objective of this project is to develop viable solid oxide fuel cell (SOFC) sealing concepts based upon self-healing glass-based seals. In this project composite seals combining suitable "self-healing" glasses with fillers and/or fibers shall be developed and evaluated. The ultimate goal is a reliable, stable, cost-effective sealing system for SOFCs.

LG Fuel Cell Systems (LG), formerly Rolls-Royce Fuel Cell Systems, will lead a team to develop low cost solid oxide fuel cell (SOFC) technology for use in highly-efficient and technologically-integrated central generation power plant facilities fueled by coal synthesis gas. The project consists of three elements, cost reduction research and development (R&D), systems R&D, and a manufacturing element. The project will utilize LG proprietary segmented-in-series SOFCs at pressures up to seven atmospheres. These cells are created by screen-printing the active cell layers (anode, cathode, and electrolyte) onto ceramic flat substrates. Each ceramic flat substrate contains a large number of small planar cells connected in series (segmented-in-series design).

The overall objective of this project is to develop a multi-physics solid oxide fuel cell (SOFC) model(s) for performance calculations of the Rolls-Royce Fuel Cell Systems (RRFCS) fuel cell in support of product development and design. The RRFCS fuel cell includes the integrated planar cell, cell assemblies that form bundles, bundle assemblies that form strips and multiple strips that define the fuel cell block. The fuel cell block is the fundamental repeat unit, and when replicated, defines a 1MW(e) fuel cell module.

This project is designed capture and explore quantitative aerodynamic and film cooling effectiveness data essential to understanding the basic physics of complex secondary flows. This includes their influence on the efficiency and performance of gas turbines, and the impact that differing film cooling ejection arrangements have on suppressing the detrimental effect of these secondary flows.

This project emphasizes enhancing the scientific understanding the underlying factors affecting combustion for current IGCC syngas turbines and using that knowledge to developed detailed, validated combustion kinetics models that would be useful to support the design and future R&D needed to transition to nearly pure high hydrogen content (HHC) fuels derived from coal syngas. The research scope fundamentally seeks to shed light on (and resolve) previously reported literature discrepancies between published experimental data and modeling predictions of early ignition behavior of syngas and HHC fuels under controlled laboratory conditions (e.g., shock tubes, rapid compression machines, counterflow burners) by pursuing very comprehensive experimental studies and detailed reaction kinetics modeling.

This project is focused on developing novel coatings for high-H2 fired gas turbine components such that high efficiencies and long lifetimes may be achieved in Integrated Gasification Combined Cycle (IGCC) powerplants. Nanostructured Hafnia-based coatings will be developed for thermal barrier coatings (TBCs). A fundamental understanding of TBCs will be acquired and a knowledge database of next generation TBC materials with high-temperature tolerance, durability, and reliability will be generated.

The objective of this project is to evaluate the use of composite polymer membranes and porous membrane contactors for the recovery of CO2 from CO2-rich solvent streams from coal gasification syngas. This work will also be applicable to similar post-combustion carbon capture systems. This project will support at least 2 graduate students during the research effort.

This project has developed, tested, and deployed a scanning eye-safe diode laser-based Differential Absorption Lidar (DIAL; LIDAR = Laser Induced Differential Absorption Radar). This instrument was designed to perform near-surface mapping of CO2 number densities for MVA to determine possible CO2 leakage to the atmosphere at geologic carbon storage sites. Horizontal testing of the CO2 DIAL instrument was conducted to determine its performance at the Zero Emission Research Technology (ZERT) field site during a controlled release experiment, and at the Kevin Dome site in north-central Montana, where the Big Sky Carbon Sequestration Partnership will be conducting a larger-scale carbon storage demonstration project. At both sites, the DIAL instrument measured CO2 concentrations that compared favorably to those measured by commercial CO2 instrumentation.

Monitoring carbon-sequestrated deep saline aquifers using existing geophysical tools is a challenge. This three-year project , performed by the University of Wyoming (UW) with assistance from WesternGeco (Houston, Texas), combines reservoir flow simulation with 3-D, multicomponent seismic waveform modeling to investigate whether seismic waveform inversion can accurately predict and account for post-injection CO2 saturation within carbon-sequestrated deep saline aquifers. If successful, this research could establish the feasibility of a practical and cost-effective technique to monitor these aquifers, which are considered to be among the most promising geologic formations for high-capacity sequestration of CO2 captured from power plant emissions and other sources.

This project will develop a high temperature, chemically stable, and carbon dioxide perm-selective dual phase membrane and conduct experimental studies on its use in a membrane reactor for water-gas-shift reaction to produce hydrogen and carbon dioxide rich streams. The goal is to identify experimental conditions for water-gas-shift reaction in the dual-phase carbon dioxide selective membrane reactor that will produce the hydrogen and CO2 streams with 93 percent and 95 percent purity. The project includes modeling studies on the performance of the WGS reaction in the new dual-phase membrane reactors and process economic analysis.

The overall objective of this program is to develop cost effective separation technology for CO2 capture from synthesis gas based on a hollow fiber membrane contactor that has the potential to provide a step change reduction in the cost of separating and capturing CO2. The objectives of Phase I work are the development of hollow fiber membranes suitable for the membrane contactor application with improved mass transfer, establishing feasibility of the proposed technology for CO2 separation from synthesis gas, and performing initial process design and economic analysis based on test data. The objectives of Phase II work will scale up the process from lab to a larger bench scale.

Research Triangle Institute (RTI) is designing, building, and testing the warm temperature desulfurization process (WDP) at pre-commercial scale (50 megawatt electric equivalent [MWe]) to remove more than 99.9 percent of the sulfur from coal-derived synthesis gas (syngas). RTI is integrating this WDP technology with an activated methyl diethanolamine (aMDEA) solvent technology to separate 90 percent of the carbon dioxide (CO2) from shifted syngas. The Polk Power Station, an integrated gasification combined cycle (IGCC) power plant, will supply approximately 20 percent of its coal-derived syngas as a slipstream to feed into the pre-commercial scale technologies being scaled-up. This project builds on the technical progress on the warm syngas cleaning technologies made during field testing with real syngas from Eastman Chemical Company's gasifier under DOE Contract DE-AC26-99FT40675. Successful warm gas cleanup, in combination with carbon capture and storage, will demonstrate high-purity syngas at significantly lower costs than current technologies.

The proposed project, Process/Equipment Co-Simulation on Syngas Chemical Looping (SCL) Process, is to conduct comprehensive and consistent co-simulation that validates the technical and economical attractiveness of the chemical looping system using the combination of computational fluid dynamics (CFD) software FLUENT® and process simulator Aspen Plus® on the platform of NETL's Advanced Process Engineering Co-Simulator (APECS). The proposed project will provide (1) detailed and reliable information for general thermodynamic analysis on SCL systems, (2) reaction mechanisms between porous oxygen carries and gas reactants, (3) distributed gas-solid contacting pattern involved in main reactors, and (4) overall material, heat and energy balance in different configurations of the whole SCL process.

The project aims to develop high performance sorbents that are capable of achieving 90% CO2 removal, having high loading capacities, and operate at the high temperatures and pressures typically encountered upstream of a WGS reactor.

The project is to develop single-crystal sapphire fiber based sensors for in situ measurement of temperature (up to 1600°C) and dynamic gas pressure in harsh environments. It will also conduct fundamental and applied research that leads to successful single-crystal sapphire fiber hybrid extrinsic/intrinsic Fabry-Perot interferometer (HEIFPI) sensors. A multidisciplinary research team from Missouri University of Science and Technology (MST) and University of Cincinnati (UC) will collaboratively focus on solving the fundamental and engineering challenges. MST and UC will model the HEIFPI sensor in response to temperature and pressure. A fully optimized measurement system integrated with high quality sapphire sensors is the objective.

The objective of this project is to develop a new type of nanocrystalline doped-ceramic-coated optical fiber sensor suitable for in-situ and real time gas monitoring in fossil energy systems. One technical objective is to identify single-phase or heterophase doped-ceramic sensor materials with desirable chemical, structural, and optical properties for the detection of fossil fuel gases. Another goal is to synthesize nanocrystalline ceramic films and protective silicalite layers on structured optical fibers. Another objective is to design and fabricate structured fiber devices for enhanced sensor performance. A final objective is to test the developed sensors in simulated high temperature and pressure fossil fuel environments.

The project objective is to develop a low cost, high capacity CO2 sorbent and demonstrate its technical and economic viability for pre-combustion CO2 capture. First year objectives include optimizing chemical and physical properties of the sorbent, scaling-up sorbent production, and beginning long-term sorbent testing in the presence of contaminants for approximately 10,000 cycles in a laboratory reactor. Second year objectives include designing and building a prototype test unit and testing the unit in the presence of actual syngas. Technology success will be based on the sorbents ability to remove CO2 at a lower cost than current technologies.

This work will focus on deriving, implementing and testing agent objective functions that promote coordinated behavior in large sensor networks. The long-term objective of the proposed work is to provide a comprehensive solution to the scalable and reliable sensor coordination problem to lead to safe and robust operation of advanced energy systems.

The objective of this project is to design, build, and test a tunable diode laser sensor capable of measuring gas concentrations and temperature in a gasification system. Two crucial sensors needs for the production and utilization of syngas have been identified: (1) to control the temperature of the gasifier by adjusting feed rates of fuel and oxygen to the gasifier and (2) to control the air dilution at the intake to the gas turbine. To address these needs, the laser-based sensor will be capable of measuring H2O, CO, CO2, and CH4; concentrations in the high-temperature, high-pressure gasifier environment. The CH4 concentration in the output syngas stream serves as a surrogate monitor of gasifier temperature. CO and CO2 concentrations have the potential to be used as a control variable for the gasifier and the subsequent utilization (e.g., gas turbine) of the syngas. Measuring water vapor absorption of laser light is used for real-time in situ temperature sensing.

This project will produce a prototype membrane that will separate hydrogen from coal-derived synthesis gas (syngas) at operating conditions found at a typical coal gas facility without the use of precious metals. The membrane will be a multi-stacked wafer of ceramic or ceramic-composite material which will meet the following standards of operation: (1) hydrogen flux of greater than 200 standard cubic feet per hour per square foot (scfh/ft2), (2) manufacturing cost of less than $100/ft2, and (3) efficient operation at relevant conditions. This research will enhance performance and efficiency as well as reduce the cost of hydrogen separation membrane technology. These advances are key to DOE's goal of achieving an affordable method of producing hydrogen from syngas in an environmentally clean manner.

This project will develop a magnetically fluidized bed reactor system that uses a chemical looping process with metal oxide sorbents to separate hydrogen from coal-derived synthesis gas (syngas). Chemical looping is a strategy for extracting high purity hydrogen and isolating sequestration-ready carbon dioxide from syngas near gasification operating conditions to obtain improved thermal efficiency over more traditional gas separations methods that operate at low temperatures and pressures. Metal oxide sorbents with magnetic properties will be studied for the potential to reduce pressure drop, provide more uniform solids distribution, and to aid in solids transport within the fluidized bed reactors. The project will experimentally explore, model, and evaluate the feasibility of this method as a pathway for meeting the DOE goal of reducing the cost of hydrogen from coal and for facilitating the production of affordable, environmentally clean energy from coal resources.

The Methanol Economy project at USC is developing the fundamental science to convert CH4 and/or CO2 into methanol (or dimethyl ether, DME) as a fuel and feed-stock. Initially, direct electrophilic bromination of CH4 to methyl bromide followed by hydrolysis to methanol/DME will be probed. Subsequently, bireforming of CH4 and CO2 and steam to syngas for conversion to methanol and DME will be studied. Some aspects of chemical and electrochemical reduction of CO2 will also be investigated. The main goal is to develop renewable sources of energy carriers that can help reduce U.S. dependence on fossil fuels, and recycle CO2 into new fuels and materials.

WPI proposes a novel dense membrane technology for the separation of H2 from syngas based on non-precious group metal (PGM) supported molten-metal membranes (SMMMs). These would comprise a thin film (3-25 mm) of a liquid metal or alloy, with a melting point in the range of 200-500C, and supported on a porous ceramic or porous metal support. The proposed membranes would be inexpensive, more robust to species such as CO, and substantially resistant to poisons such as sulfur. In addition, they would obviate issues related to solid dense membranes; sintering, H2 embrittlement, thermal mismatch between the membrane and the support, and formation of pin-holes.

The overall objectives of the proposed research by UTD are to prepare novel, non-precious metal mixed matrix membranes, in flat and hollow fiber geometries, based on polymer composites with nanoparticles of zeolitic imidazolate frameworks (ZIFs). Membrane performance to separate hydrogen from synthesis gas (e.g. H2, CO, CO2, H2O) generated during coal gasification will be evaluated in an integrated water gas shift membrane reactor using NETL test protocols (DOE/NETL-2008/1335). The goal is to exploit the high surface areas, adsorption capacities, and sieving capabilities of the nanoporous ZIF additives to achieve unprecedented, selective transport of hydrogen under operating conditions defined by 2015 DOE targets.

The Consortium for Fossil Fuel Science (CFFS) is a multi-university research consortium with participants from the Universities of Kentucky, West Virginia, Pittsburgh, Utah, and Auburn. The proposed three-year research program is focused on: (1) developing novel processes for the production of hydrogen using C1 chemistry; (2) developing novel hydrogen storage materials; and (3) synthesis and dehydrogenation of hydrogen-rich carrier liquids. The feedstocks include synthesis gas derived from coal, gaseous and liquid hydrocarbons produced from coal-derived syngas, coalbed methane, and natural gas.

The objective is to develop novel modified fiber materials for high temperature gas sensors based on evanescent wave absorption in standing hole optical fibers. To overcome the response time limitation of currently available holey fibers (due to gas phase diffusion constraints), a novel process will be developed to produce holes perpendicular to the fiber axis. An investigation of the feasibility of upgrading the technology to single crystal sapphire by use of sol-gel processing and laser backside photochemical etching will be accomplished, thereby providing a quantum leap in temperature capability of the gas sensor.

Petra Nova Parish Holdings, a joint venture between NRG Energy and JX Nippon Oil and Gas Exploration, will retrofit a CO2 capture plant on an existing coal-fired power plant (W.A. Parish Generating Station) located in Thompsons, Texas, which is southwest of Houston. The project will demonstrate the ability of the CO2 capture technology supplied by Mitsubishi Heavy Industries (MHI) to capture 90% of the CO2 emitted from a 240 megawatt electrical (MWe) flue gas stream. The MHI CO2 capture technology, called the KM CDR Process (Kansai Mitsubishi Carbon Dioxide Recovery), was jointly developed by MHI and the Kansai Electric Power Company. This process uses the proprietary KS-1™ solvent that facilitates low energy requirements, solvent consumption, and waste products, when compared with a conventional solvent.

The project is designed to capture and store 1.4 million tonnes of CO2 per year. At 240 MWe, this will be the largest post-combustion CO2 capture project installed on an existing coal-fueled power plant. This project has the potential to enhance the long term viability and sustainability of coal-fueled power plants across the United States and worldwide. The University of Texas, Bureau of Economic Geology will design and manage the CO2 monitoring plans for this project.

The goal of this project is to create a center with a unique fully equipped laboratory capable of fabricating pilot quantities of new energy efficient construction materials from coal products and testing them. The center will be operated by a full time staff devoted to developing new products and industries that manufacture construction materials from coal combustion products or CCP's

Under this project, Pennsylvania State University (PSU) will develop a new generation of solid polymer-based sorbents for more efficient capture and separation of carbon dioxide (CO2) from flue gas of coal-fired power plants. The project is based on the concept of a "molecular basket" sorbent (MBS) which was invented and developed at PSU. The idea of MBS development is to load CO2-philic polymers onto high surface area mesoporous materials. This process increases the number of approachable sites on/in the sorbent and enhances the sorption/desorption rate by increasing the gas-sorbent contacting interface and by improving the mass transfer in the sorption/desorption process. The expected result of this project will be a concentrated CO2 stream that can be directed to CO2 sequestration or CO2 utilization.

The second Cooperative Agreement (DE-FE0003466) supporting the National Center for Hydrogen Technology (NCHT) Program will continue to build on the proven approach and accomplishments obtained during the first five years of the program. The Center will continue to focus on the research and development activities that are required to develop advanced hydrogen production and delivery technologies from fossil fuels. The result of these activities will improve current technology and make available new, innovative technology that can produce and deliver affordable hydrogen from coal, the most abundant fuel resource of the U.S., as well as from other fuels, with significantly reduced or near-zero emissions.

The following investigations, to be carried out within a two-year period, are proposed: (1) the simulation method development: Develop reliable interatomic potentials from the highly accurate ab initio molecular dynamics (MD) calculation for Cr-Y and Cr-Ta systems. (2) The application of the simulation method for novel material design: Set up Cr-Y and Cr-Ta models and perform the HPC MD simulation on the Cr based alloy models to study the high temperature properties and the oxidation and sulfate corrosion resistance capabilities. (3) Method validation: Perform experiments on the oxidation and sulfate corrosion resistance of the most promising systems identified by the simulation. The isothermal oxidation and corrosiveness kinetics of Cr based alloy samples will be studied at high temperature in air and at sulfate corrosive environment by thermal-gravity analysis (TGA), differential scanning calorimeter (DSC), and in a high temperature rig. The primary theoretical method of investigation is the ab initio molecular dynamics method based on the density functional theory (DFT).

The overall project goal is to develop a high speed particle imaging method by which to obtain a full-field visualization of rotational motions of non-spherical particles in quasi-2-dimensional semi-dilute (volume fractions of 10 or 15%) flows and to take into account drag force interactions between bidisperse non-spherical grains and fluid flow.

The research carried out in this project encompassed three general areas: (i) assessment of relevant radiation properties of particle clouds encountered in fluidized bed and pulverized coal combustors, (ii) development of proper spectral models for gas–particulate mixtures for various types of two-phase combustion flows, and (iii) development of a radiative transfer equation (RTE) solution module for such applications. The resulting models were validated against artificial cases since open literature experimental data were not available. The final models are in modular form tailored toward maximum portability, and were incorporated into two research codes: (i) the open-source CFD code OpenFOAM, which had been extensively used in previous work, and (ii) the open-source multi-phase flow code MFIX, which is maintained by NETL.

The overall goal is to provide valuable insight in to the mechanisms and processes that could lead to next generation hot section material operating at temperature beyond 1350°C which could play an important role in current plight towards greener energy. The main objectives of the proposed projects are: (1) developing a supercell approach to evaluate physical properties of alloys which maintains various order and disorder bulk phases and interfaces; (2) applying the supercell approach to study the physical properties of Nb-Si alloy. The results will be used to guide the search for optimal Nb-Si alloy design with a balanced set of physical properties.

This project will develop high resolution methods for modeling the three dimensional mechanical response of metallic alloys when exposed to high temperatures. The methodology will include three (3) dimensional microstructure generation from microscopy data, and an image-based method for high resolution simulation of mechanical response. The technical focus will be on simulating plastic deformation and damage accumulation of polycrystalline materials at the grain scale.

Researchers at West Virginia University (WVU) will develop micro-scale, chemical sensors and sensor arrays composed of nano-derived, metal-oxide composite materials to detect H2 and H2S within high-temperature environments (500-1200ºC). Most micro-patterned semi-conductor based chemical sensors use thin film deposition and wet/dry etching processes. This work will demonstrate an innovative microcasting process for forming chemi-resistive sensors with 20-100 µm feature size of various geometries composed of nano-composite electrodes that display high-temperature microstructural and morphological stability. In order to achieve this goal, the work will concurrently address issues relating to electrode stability, selectivity, and sensor miniaturization.

Based on a recent discovery of premelting-like GB segregation in refractory metals occurring at high temperatures and/or high alloying levels, the proposed research will investigate GB segregation and embrittlement in tungsten (W) based alloys as model systems. The overall objective is to develop a theoretical framework in combination with a multiscale modeling strategy for predicting GB segregation and embrittlement. The project is divided into three tasks (seven subtasks) in two phases . The key objectives for a 2-year Phase I are developing (a) a quantitative model for predicting GB segregation in ternary W alloys, (b) a multiscale modeling strategy to predict GB embrittlement from GB segregation, and (c) the experimental validation and support. A 1-year Phase II will validate and refine models and conduct several exploratory studies.

The main objective of this project is to carry out extensive computational modeling on Mo-based composite alloys that can be used in a high temperature high pressure environment for applications in fossil energy conversion technology. Specifically the objectives are: (1) To develop a new method for calculating thermomechanical properties at extreme conditions based on ab initio calculation of the phonon spectra; (2) to explore materials for fossil energy applications in the Mo-Si-B system using a supercell approach; (3) to understand the fundamental mechanism for the enhanced thermomechanical properties of the modeled structures in relation to their electronic structures; and (4) to establish effective collaborations with scientists at DOE laboratories and at other institutions to accelerate the materials development for fossil energy technology.

This project aimed at demonstrating the feasibility of a CO2 utilization process for producing carbon monoxide and a variety of other useful products based on reduction of CO2 using abundant low-value carbon sources such as petcoke, sub-bituminous coal, lignite, and biomass. The chemical process is based on the reverse Boudouard reaction, in which carbon (C) reduces CO2 to produce carbon monoxide (CO). The reduced product (CO) can then be used to create other chemicals. A preliminary techno-economic analysis for the process showed that it had a promising rate of return on investment. The project also included an investigation of direct chemical production using CO2; specifically, the potential for producing ethylene and dry reforming of methane. Several catalysts developed and optimized in this project demonstrated production of ethylene at temperatures between 800°C and 900°C. For dry reforming, a catalyst formulation developed on this project demonstrated reactivity at temperatures between 500°C and 600°C. These results show that with suitable catalysts, CO2 utilization can be used to produce many of the large volume commodity chemicals currently manufactured.

The Zero Emission Research and Technology Center (ZERT) is a research collaborative focused on understanding the basic science of underground (geologic) storage of carbon dioxide (CO2) to mitigate greenhouse gas emissions from fossil fuel use. The ZERT II project will develop a comprehensive approach to measurement, monitoring, mitigation, and risk assessment for geologic CO2 sequestration, including fundamental studies of geophysical and geochemical interactions of CO2 with formation waters and minerals, development of new monitoring methods or suites of methods, parameterization of potential leakage / seepage mechanisms and assessment of reservoirs relevant to these mechanisms.

A CO2 sorbent regeneration process will be experimentally and computationally studied. The experimental effort will include obtaining the data necessary to determine the intrinsic reaction rates and diffusivity parameters for the CO2absorption/regeneration and the WGS reactions. A multi-phase Computational Fluid Dynamics (CFD) model is proposed which includes a population balance equation governing the particle porosity distribution (PPD) evolution. The CFD/Population Balance Equation (PBE) model will be numerically solved and simulations of the regenerative carbon dioxide removal process will be performed; the Finite size domain Complete set of trial functions Method Of Moments (FCMOM) numerical technique will be used and developed to solve the PBE. The simulation results will be used to determine the optimum reactor configuration/geometry and the operating conditions for the CO2 removal and hydrogen production.

The project will conduct materials and device research and development. The initial phase of work will focus on the sensing mechanism of LaBaCo2O5 thin films. Work includes optimization of the fabrication conditions and determination of the general characteristics and sensing mechanism of the highly epitaxial LaBaCo2O5.5 thin-films including surface exchange, reactivity and stability. The second phase of work will fabricate and demonstrate a resistive chemical sensor system for high temperature applications.

The scope of the work proposed is two-fold. Researchers will first use a laser nano-fabrication technique to produce 3D structurally functional metal-oxide nano-materials for high-temperature gas sensing. Then, functional metal oxides will be integrated on high-temperature optical sensor platforms. Researchers will fabricate three-dimensional photonic crystals using functional metal oxides, utilizing a robust and simple approach to construct multi-beam interference patterns using a single diffractive optical element. Additionally, femto-second laser processing techniques will be used to produce high-temperature stable fiber grating sensors and long-period grating based in-fiber interferometer. The final aspect of the research effort includes coating metal-oxide nano-films inside the hollow core optical fibers to enhance the Raman and the photo-luminescence signals for gas sensing. The large surface area of nano-composite metal-oxides will serve as effective gas absorbers to reduce the fiber length needed for high-sensitivity measurements. Using coated hollow-tube waveguides, a number of spectroscopy studies will be performed to assess the feasibility of fuel gas sensing at high temperature.

Brown University researchers have demonstrated the viability of a bench scale reaction to utilize carbon dioxide and ethylene as reactants in the production of valuable acrylate compounds with low-valent molybdenum catalysts. Exploratory experiments have been conducted to identifying those factors which control the current catalyst limiting step in acrylic acid formation. The project consisted of three project phases. Phase I expanded the range of molybdenum complexes capable of coupling CO2 and ethylene by defining the available ligand architectures which facilitate acrylate formation. Phase II leveraged computational and experimental mechanistic investigations to determine the catalyst coordination environment and reaction conditions necessary to enhance the catalytic limiting step, reductive acrylate elimination. Phase III included the design and preparation of an optimized molybdenum catalyst(s) for a bench scale reaction to test the feasibility of molybdenum catalyzed acrylate formation from CO2.

This program will provide an improved mechanistic understanding of the degradation of critical turbine system materials in HHC-fueled systems, and guide the development of more robust materials sets ultimately advancing the goals of the DOE Advanced Turbine Program. These developments will assist in developing coal-derived fuel based turbine systems, facilitating use of domestic energy resources.

This project has developed and demonstrated a method to rapidly, cost effectively, and efficiently perform technical assessments of major engineering and scientific issues considered to be critical to the design, implementation, and operation of a saline aquifer CO2 storage sites and enhanced oil recovery operations. The research effort integrated well completion design, including effects of geomechanical stresses, into a static reservoir model coupled with reactive transport simulation. Model simulations enable CO2 storage sites assessment of geologic and fluid effects and factors on CO2 injection, capacity, and plume migration.

The primary objective of this project was to improve the understanding of CO2 trapping mechanisms affected by formation heterogeneity. The basic processes of CO2 trapping are not easily understood through field testing, so a set of multi-scale laboratory tests were conducted to further analyze CO2 trapping mechanisms. The focus of the research was to analyze capillary and dissolution trapping mechanisms since they are considered to be the most relevant processes facilitating permanent CO2 storage in the absence of geologic structural traps. The ultimate goal was to contribute towards improving numerical modeling tools for designing stable CO2 storage operations with optimized storage efficiency and minimized leakage risks.

The over-arching objective of this project is to conduct a multiscale, multiphysics, interdisciplinary laboratory study that assesses the feasibility of depleted organic-rich gas shale reservoirs for large-scale CO2 sequestration. This project elucidates mechanisms of CO2 injectivity, the formation geomechanical response, CO2 transport through fractures and matrix, storage security through a trap and seal framework, and lays the foundation for accurate estimates of storage rates as well as capacity. Experiments provide data for verification and validation of models to estimate CO2 sequestration capacity and storage effectiveness of gas shales under realistic conditions. Four broad research task areas are examined: (1) physical and chemical aspects of CO2/shale interactions, (2) transport and mobility of critical state CO2 in hydrofracs, natural fractures and pores, (3) ground water/shale/stored CO2 interactions, and (4) trap and seal analysis of CO2 storage in gas shale reservoirs. The scope of activities represents more than 124 man months of effort.

Membrane Technology and Research (MTR) and partners will validate at pilot scale a cost-effective membrane process to separate CO2 from coal-fired power plant flue gas. The MTR innovative membrane design utilizes two key innovations: high CO2 permeance membranes and a countercurrent sweep module design. This project will advance MTR's membrane technology to the 1 MWe level. MTR will continue to operate an existing 0.05 MWe slipstream field test system, located at the National Carbon Capture Center (NCCC), to optimize membrane materials and module designs. A 1 MWe membrane skid capable of 90% CO2 capture from a 20 ton CO2 per day slipstream of coal-fired flue gas will be designed, constructed, and installed at the NCCC for a six-month field test. MTR's air sweep process design will be evaluated in collaboration with Babcock & Wilcox to determine the performance impact of retrofitting existing boilers. The Electric Power Research Institute will evaluate the benefits of flue gas water recovery, measure the quality of the water produced, and define water management for the integrated CO2 capture process. Results from the 1 MWe skid test program will be used to update a comparative economic analysis of the MTR membrane process to clarify the potential of the MTR membrane process and identify key cost-reduction milestones and success criteria necessary to meet the Department of Energy program goals. Predecessor Project: DE-NT0005312 Successor Project: DE-FE0013118

ADA Environmental Solutions (ADA-ES) will design, construct, and operate a 1 megawatt electric (MWe) pilot-scale test unit to evaluate the performance and cost of an advanced solid sorbent-based carbon dioxide (CO2) post-combustion capture technology for coal-fired power plants. ADA-ES evaluated over 100 potential CO2 sorbents to select sorbents for scale-up that are stable, have relatively high CO2 capacity, and have lower heats of reaction than carbonate-based solids. The project will utilize progress on sorbent technology validated at bench scale in a separate Department of Energy (DOE) project (DE-NT0005649) and will refine and optimize sorbent capture and regeneration processes through pilot testing and process modeling. Project results will be used to develop a preliminary full-scale commercial design in preparation for demonstration at the next scale. Predecessor Project: DE-NT0005649 Successor Project: DE-FE0012914

The Department of Energy's National Energy Technology Laboratory (NETL) has entered into a collaborative agreement with the West Virginia University's National Research Center for Coal and Energy (WVU-NRCCE) to further expand on the existing research efforts previously initiated with the construction of the Hydrogen Research, Development, Test and Evaluation (RDT&E) facility located at the Yeager Airport in Charleston, WV. This expansion will be focused on the development of a second hydrogen fuel production, storage and dispensing facility to be located in Morgantown, WV. When completed in the following year, this facility will be capable of generating, storing, and dispensing hydrogen as a fuel source for various types of hydrogen internal combustion engine (ICE) and fuel cell-powered vehicles and equipment. Hydrogen is considered a fuel of the future because it does not produce air pollutants when used - clean water is the only byproduct. The electricity for the electrolysis of water to produce pure hydrogen fuel at the Morgantown facility will come from coal-based power generation. The open system architecture design centers on two value propositions: (a) that two cents worth of water holds a kilogram of hydrogen and is an excellent feedstock for production by electrolysis using electric power, and (b) that off-peak grid electricity is undervalued and can be effectively used in hydrogen production. The purpose of this Hydrogen Fuel Dispensing Station project at West Virginia University shall begin with site development and installation of some of the key equipment needed for a Research Development Test & Evaluation (RDT&E) platform that will produce and dispense hydrogen fuel (H2). The WVU Hydrogen Fuel Dispensing Station will duplicate the design and performance of the Yeager Airport Hydrogen Fueling Station by using modular layout and an open architecture. This open architecture will support the evaluation of components, devices, subsystems and systems for hydrogen energy. As with the Yeager Airport H2 Station, a modular layout will allow for site flexibility and adaptability. The site development and installation of some major pieces of station equipment will move USDOE, West Virginia and West Virginia University closer to creating a hydrogen corridor by taking steps to establish a second, northern terminus along the I-79 corridor.

Solidia Technologies, Inc. (Solidia) is working to create an energy-efficient, carbon dioxide (CO2)-consuming inorganic binder based on a patented synthetic Wollastonite material known as Solidia CementTM (SC) that will act as a suitable substitute for Portland Cement (PC). The process developed by Solidia utilizes a binding phase based on carbonation chemistry rather than conventional hydration chemistry (i.e., curing by adding water). During CO2-curing, SC was demonstrated to consume 250kg of CO2 per metric ton SC produced (30% by weight). The project initially started with an investigation of the effect of temperature, pressure, and particle size on the carbonation reaction rate and yield. Solidia further optimized the curing process at bench scale by analyzing the effect of water distribution and drying on the curing process. Solidia then successfully produced several full-scale product forms (railroad ties, concrete block, and hollow core slab) that exceeded performance standards. Solida is currently performing commercial trials at several precast concrete manufacturers to demonstrate feasibility of retrofitting to existing facilities at comparable production economics.

Researchers at PhosphorTech Corporation have modified conventional photocatalyst materials to improve their ability to convert/reform CO2 into other useful chemicals in a cost-effective and energy efficient manner. A photocatalyst is a material that speeds up a chemical reaction when subjected to sufficient light energy (sunlight in this study). To date, even the most efficient conventional photocatalysts suffer from extremely low concentration yields (0.01-0.1 volume percent), making them impractical for commercial applications. Researchers are making efforts to improve performance in order to enhance the efficiency and cost-effectiveness of these technology types for reforming CO2.

Researchers at the Massachusetts Institute of Technology (MIT) and Siemens investigated the feasibility of integrating CO2 from emission sources (power plants, manufacturing facilities, cement plants, or fertilizer facilities) into a chemical reaction process that creates organic carbonate commodity chemicals for later use. The researchers also designed electrochemical processes which allow for continuous capture of CO2 followed by cyclic organic carbonate synthesis using organocatalysts. They conducted multiple lifecycle analyses of the electrochemical process and commodity chemicals synthesized during chemical CO2 storage process. The basis of the capture technology is the chemical affinity of electrochemically active carriers for CO2 molecules. These carriers facilitate the effective capture of CO2 from a dilute gas stream (effluents from CO2 emitters) through the formation of chemically activated species. The organocatalytic CO2 conversion processes have been demonstrated to be a high-yielding continuous synthesis for the production of cyclic carbonates from CO2 and epoxide as well as an efficient cyclic carbonate synthesis from CO2 and olefins.

This project used four dimensional (4D) seismic data from the Sleipner project in the Norwegian North Sea to conduct multiphase flow and reactive mass transport modeling of CO2 migration in the reservoir. Researchers at Indiana University used the geologic model provided by StatOil to develop a reservoir scale multi-phase reactive flow model for CO2 plume migration and dynamic evolution of CO2 trapping mechanisms (hydrodynamic/structural, solubility, mineral, and residual/capillary) at Sleipner. The reactive flow model was calibrated through history matching with progressive CO2 plume migration delineated by 4D seismic data. The calibrated reservoir model was then extrapolated to a regional scale model of multi-phase reactive mass transport to predict the fate of CO2 10,000 years after injection. A rigorous geochemical reaction kinetics framework was implemented and a number of sensitivity analysis and bounding calculations were used to aid in the reduction of uncertainty in predictions of geochemical reactions.

Clemson University has characterized wellbore deformation under conditions anticipated during geologic CO2 storage, identifying and evaluating techniques for interpreting the results of simultaneous measurements of displacement and pressures during well testing or operations, and evaluating capabilities and requirements for downhole geomechanical instrumentation. Wellbores can deform in response to the injection or recovery of fluid. In extreme cases, the deformation is catastrophic and the well can be compromised. Wellbores can potentially deform during carbon storage operations, and effective monitoring of this process can be used to detect early precursors to fracturing within the injection formation, induced faulting, and failure of wellbore seals so they can be addressed before becoming catastrophic.

This Georgia Tech project will improve the state-of-the-art understanding of turbulent flame propagation characteristics of high hydrogen content (HHC) fuels. The turbulent flame speed has a leading order influence on important combustor performance metrics such as flashback and blow-off propensities, emissions, life of hot section components, and combustion instabilities limits, including operating limits required to prevent harmful combustion dynamics. This research specifically addresses three of the combustion topic areas identified by Department of Energy (DOE) as of great importance for HHC systems: (1) turbulent burning velocities, (2) flash-back, and (3) exhaust gas recirculation (EGR) impacts. The results of this effort will also enable advances in several other combustion topic areas; e.g., predicting combustion dynamics (which requires flame shape predictions) and improving large eddy simulation capabilities by providing turbulent burning rate sub-models for HHC fuels. The project involves both experimental and modeling efforts. Prior work used optical flame emission in measurement of global turbulent consumption speeds of hydrogen (H2)/carbon monoxide (CO) fuels. For this project, researchers will extend these previous efforts to a broader reactant class, including mixtures diluted with CO2, water (H2O), and nitrogen (N2). Depending upon the degree of dilution, these mixtures will simulate both gasified fuel blends and systems with EGR. This data will be used to further the development of physics-based, mixture-dependent models of turbulent burning rates and to guide selection of conditions for determining more localized measurements of turbulence/chemistry interactions. Specifically, high-repetition-rate particle image velocimetry and hydroxyl radical planar laser induced fluorescence systems will be used to determine local flame speeds under realistic turbulent conditions. This is necessary for developing an improved understanding of strained flame statistics, and for testing and refining propagation models based on leading point concepts. The work plan will initially focus on uniform, premixed reactant mixtures, and then expand in focus by investigating turbulent burning rates in inhomogeneous premixed flows. An example would be obtaining measurements of turbulent propagation speeds in mixtures with stratified fuel/air profiles.

The project was used to evaluate the effectiveness of a new seismic tool, volumetric curvature (VC), to identify the presence, extent, and impact of paleokarst heterogeneity and faulting structures on geologic CO2 storage in the Arbuckle Group, a saline carbonate formation in southwestern Kansas. Existing seismic and well data were reprocessed and analyzed using VC analysis. An integrated geologic model was then developed to indirectly confirm the presence of VC identified compartments, as well as to estimate geologic storage capacity, optimum CO2 injection rate that could occur, potential CO2 plume migration, reservoir containment, and CO2 leakage risk. A horizontal well was installed to intersect the paleokarst features and confirm that the imaged seismic feature was present.

This collaborative effort studying technologies important to the reliability of high hydrogen fueled gas turbines has been structured utilizing three phases. Phase I: Leading Edge Model Development and Experimental Validation The initial task for The Ohio State University's (OSU's) turbine reacting flow rig (TuRFR) facility will be to determine if the deposition mechanism for faired cylinders is similar to deposition for turbine vanes. If this approach is feasible, then the relative impact of leading edge diameter on deposition can be investigated using varying diameter cylinders instead of vanes. The deposition measurements will then be made and sent to the University of North Dakota (UND) for surface modeling. During Phase I, UND will study the response of turbulence approaching large cylindrical stagnation regions, the associated heat transfer augmentation, and boundary layer development on the cylinder's surface. Additionally, UND will begin the development of candidate internal cooling geometries for cooling a region of a turbine vane leading edge. Phase II: Experimental Deposition and Roughness Study: OSU will utilize the TuRFR facility, modified to generate higher levels of turbulence, to study the influence of turbulence on deposition rates in turbines. These results will be used to improve predictive modeling and made available to UND for heat transfer measurements. UND will use surfaces generated by OSU as part of their leading edge heat transfer and boundary layer studies. UND will also develop and test candidate internal cooling schemes for large regions on a turbine vane's leading edge. Phase III: Mitigation of Deposition Using Downstream Full Coverage Film Cooling OSU will use faired (rounded to reduce drag) cylinders to explore various film cooling designs to assess their effectiveness at reducing deposition. Actual turbine vane geometry will be used to explore the influence of select film cooling patterns on deposition. UND will investigate the combined influence of turbulence and realistic roughness on film cooling effectiveness and surface heat transfer. As a basis of comparison, they will initially look at the influence of turbulence on film cooling effective-ness and heat transfer for selected full coverage geometries.

The objective of this effort is to assess the factors influencing effective CO2 storage capacity and injectivity in the Marcellus shale, the Utica shale, including equivalent shales in Vermont; and the Devonian Ohio shale. The work addresses approaches and/or technologies to improve injectivity and utilization of pore space. Specifically, it provides a better understanding of CO2 trapping mechanisms leading to improved storage permanence and capacity estimates in gas shales, and the effects on storage and injectivity given variable gas shale reservoir types, rock properties, and stratigraphic and structural properties. This effort builds on previous efforts, primarily in New York and Kentucky, to assess the CO2 storage potential of gas shales. The primary focus is on establishing the reservoir engineering and operational requirements to overcome the constraints imposed by shale reservoirs to achieve cost-effective CO2 storage. In other words, the goal of effort is not just to answer how much CO2 can be stored in gas shales; but also to identify the critical factors that can influence optimum CO2 storage volumes and injection rates in gas shales.

New thermal barrier coating (TBC) materials can be tested for mechanical, physical, and chemical properties by altering the bond coat and top coat compositions. Current studies on TBCs are usually performed by trial-and-error approach. As the trial-and-error process is usually very expensive and time consuming, the Louisiana State University and Southern University team proposes to design a high performance TBC with enhanced top and bond coat through a reliable and efficient theoretical/computational approach. This can be used systematically to identify promising TBC bond coat and top coat compositions. Using high performance computing (HPC) simulations, an ab initio (i.e., from first principles) molecular dynamics (MD)-based design tool can screen and identify TBC systems with desired physical properties. Such computations work from basic or fundamental laws of nature to derive effects without intervening assumptions or special models, in principle producing well-founded results. The new TBC systems will be demonstrated experimentally under IGCC environments.

Recent research data indicate that the current bill of coating materials is not directly compatible with the moisture-rich, ash-laden environment present with coal-derived high hydrogen content (HHC) fuels. Thus, Stony Brook University research focuses on a multi-layer, multifunctional strategy that includes discretely engineered coating layers to combat various technical issues through a concerted effort integrating material science, processing science, and performance studies, including recent developments in advanced, in situ thermal spray coating property measurement for full-field enhancement of coating and process reliability. This project will further the science-based understanding of thermal barrier coatings (TBCs) and elevate the roles that processing and novel materials can play in extending bond coat and top coat lifetimes, and provide a new framework for examining the processing-performance relationship in multilayer thermal barriers as a pathway for reliable integrated gasification combined cycle (IGCC) coating development, and provide new insight for the thermal spray industry. In this project, TBCs will be developed through investigation into how processing affects the oxidation behavior of metallic bond coats in water vapor environments, and by developing ceramic top coat architectures using thermal spray processing of emerging zirconate materials that have shown promise as advanced thermal barriers. Novel, in situ particle and coating state sensors will be used to accelerate process development and understand processing-microstructure relationships and process reliability. A systematic evaluation of multilayer coatings on nickel superalloys will determine properties (including microstructure, compliance, residual stress, thermal conductivity, and sintering behavior) and degradation mechanisms due to high-temperature water vapor and ash exposure as well as erosion.

Worcester Polytechnic Institute will demonstrate hydrogen separation from coal-derived syngas using palladium (Pd) and Pd alloy membranes on porous metal supports. The goal of the project is to carry out a comprehensive engineering design for advanced hydrogen-carbon dioxide (H2-CO2) Pd and Pd-alloy composite membrane separations with process intensification technologies that reduce the number of unit operations required for H2 production from a coal (coal-biomass)-based syngas.

This project aims to demonstrate small scale SOFC technology readiness for commercial scale-up. Technology Management, Inc. (TMI), the project performer, estimates that the system can reduce fuel consumption by approximately 50% compared to conventional reciprocating engine systems and proposes to validate these savings by empirical data. In addition, use of this technology operating on bio-based fuels can eliminate carbon emissions to the atmosphere associated with the power produced (equivalent to approximately 9.6 metric tons CO2/kW/year as compared to power produced from a conventional coal-fired power plant). This demonstration is noteworthy because today there are few practical alternatives for ordinary consumers to obtain their home electric energy from biofuel, a potentially attractive feature to some environmentally conscious consumers.

This project will demonstrate an application of a CoalTek, Inc. (CoalTek) proprietary microwave process for treating energy feedstock materials. The process combines coal and biomass to produce an economically viable and suitable single-stream feedstock for co-gasification. Phase I of the project will focus on microwave processing, batch-scale production, and laboratory characterizations of briquettes with the objective to identify the combinations of biomass and coal types that provide the most suitable briquetted product for co-gasification. Phase II will use a larger scale, continuous mode process to (1) demonstrate the performance of the co-briquetted fuels during co-gasification in two different pilot-plant designs, i.e., fixed-bed and fluidized-bed gasifiers, and (2) enable realistic cost estimates for the construction and operation of a commercial-scale biomass-coal briquetting plant based on CoalTek's proprietary microwave process.

The objectives of this Georgia Tech study are to obtain experimental reactor data and develop kinetic rate expressions for pyrolysis and char gasification for the coal-biomass blends under conditions free from transport limitations, to develop a detailed understanding of the effect of pyrolysis conditions on the porous char structure, to build mathematical models that combine true kinetic rate expressions with transport models for predicting gasification behavior for a broad range of pressures and temperatures, and to investigate the physical and chemical parameters that might lead to synergistic effects in coal-biomass blends gasification.

The GTI research team will subject lignocellulosic biomass (plant biomass that is composed of cellulose, hemicellulose, and lignin), in the form of loblolly pine (a lignocellulosic, short rotation woody crop), to hydrothermal carbonization (HTC), creating a densified coal-like product by exposing biomass feedstocks to heat and pressure in the presence of water. The process will deconstruct the lignocellulosic feedstock to produce aqueous and solid streams. The first stage of this work will occur at a small bench-scale facility at the Desert Research Institute to determine optimal HTC processing parameters and develop accurate mass and energy balances. The second stage will utilize larger sample sizes at a larger, dedicated Process Development Unit (PDU). Initially, the HTC product will be mixed with ground coal, pelletized, and assessed for strength and grindability. The durability of lignin and similar binders in wood when subjected to HT will be assessed. In a later phase, loblolly pine samples will be processed using HTC and internally mixed with ground coal within the PDU so that it can be directly formed to a final densified product, which will also be assessed for strength and grindability. GTI will use Aspen software (Aspen Technology, Inc.) to carry out process simulations based on engineering results attained during the project. These simulations will provide the technical basis for developing a techno-economic analysis to evaluate the economic viability of HTC for producing a new coal/HTC biomass fuel.

The objective of this project is to develop preliminary conceptual design concepts and conduct a series of techno-economic systems analyses to provide an improved understanding of the energy, environmental, and economic performance of industrial facilities that produce electricity and a fuel or chemical co-product from a mixture of coal and biomass, with capture and underground storage (CCS) of by-product CO2.

The overall goal of the project is to develop design concepts, incorporating advanced technologies in areas such as oxygen production, feed systems, gas cleanup, component separations and gas turbines, for integrated and economically viable coal and biomass fed gasification facilities equipped with carbon capture and storage for the following scenarios: (i) coproduction of power along with hydrogen, (ii) coproduction of power along with fuels, (iii) coproduction of power along with petrochemicals, and (iv) coproduction of power along with agricultural chemicals.

The project team is developing engineered systems for manufacturing coal-biomass briquettes or pellets containing 10 to 30 percent biomass that are ideally suited for transportation, storage, and direct co-feeding into industrial gasifiers. An in-depth experimental study to determine the key reactive properties for coal-biomass mixed fuels is underway, testing sub-bituminous coal mixed with biomass feedstocks of hybrid poplar wood, switchgrass, or corn stover. Enabling technology for this project includes the application of novel binding additives and, when required, an advanced conditioning process for upstream sizing, upgrading, and drying. Upon completion, the project will provide information on the equipment, necessary conditions, and process requirements for the manufacture of optimal coal-biomass feedstock for co-gasification.

This Virginia Tech project is a collaborative effort involving experiments, kinetic modeling, and computational fluid dynamics that incorporates efficient methods for solving complex heterogeneous chemistry. The goal is to determine the key reactive properties for coal-biomass mixed fuels. To achieve this goal, sub-bituminous coal will be mixed with biomass feedstocks of hybrid poplar wood, switchgrass, or corn stover and catalysts added to lower the gasification temperatures, thereby improving the gasification process. The outcome of this research will be characterization of the chemical kinetics and reaction mechanisms of the co-gasification fuels and development of a set of models that can be integrated into other modeling environments. Finally, the reaction kinetics modeling will be implemented into NETL multiphase flow code—Multiphase Flow with Interphase Exchange (MFIX)—to efficiently simulate the chemistry and recommendations will be made regarding fluidization characteristics.

Develop advanced technologies that can be used to exploit domestic energy resources and help developing countries reduce their CO2 emissions. In addition, new gas-gas separations technologies to be developed at CAST will have crosscutting applications for a wide spectrum of the Fossil Energy R&D programs.

In this three year project, Virginia Tech Center for Photonics Technology will develop a first-of-a-kind, high-temperature distributed sensing platform capable of monitoring the space- and time-varying thermal properties of an entrained flow gasifier refractory wall. The sensor operates using optically-generated transient, traveling long-period gratings in a photonic crystal optical fiber to achieve fully-distributed measurement of temperatures above 1000°C with centimeter-level spatial resolution.

General Electric Global Research Center will develop model based techniques for (1) enhancing the availability of the gasifier and radiant syngas cooler (RSC) including refractory hot surface degradation and RSC fouling and their impact on sensors; (2) implementing a nonlinear, model-based estimation algorithm to monitor the refractory condition and RSC fouling; and (3) nonlinear optimizing for optimal sensor placement (OSP) to achieve condition monitoring requirements in the presence of practical constraints on sensor types and locations. The performance of the OSP algorithm and resulting condition monitoring solution will be demonstrated using representative test cases for gasifier refractory degradation and RSC fouling. The approach will be applicable to condition monitoring of other critical components in coal-fired power plants.

The primary objectives of this project are to develop in-situ corrosion monitoring sensors for ultrasupercritical (USC) boiler tubes, that is based on WVU's patent pending technology on high temperature electrochemical characterization devices and development of thermal-electric based energy harvesting and telecommunication devices for the self-powered wireless ready sensor system. Successful completion of this project will provide an in-situ corrosion monitoring system and life-prediction toolbox for USC boiler tubes that meets the requirements of next generation USC boiler systems.

The overall objective of this work is the development of model-based sensor placement algorithms for maximizing the robustness and effectiveness of the sensor network to monitor the plant health both at the unit level and at the systems level. This will be achieved by developing a two-tier sensor network algorithm capable of performing component condition monitoring and system-level fault diagnosis. The algorithms will be implemented on a coal-based plant-wide simulation of an Integrated Gasification Combined Cycle (IGCC) with a rigorous gasifier model. The work is also extendable to similar fossil energy plants.

Researchers at McGill University worked to develop a CO2 curing process for the precast concrete industry that can utilize CO2 in place of steam as a reactant to accelerate strength gain, reduce energy consumption, and improve the durability of precast concrete products. Carbon dioxide curing of concrete is considered a CO2 storage process. As gaseous CO2 is converted to thermodynamically stable calcium carbonate, the CO2 becomes embedded in calcium silicate hydrate. Concrete masonry blocks and fiber-cement panels are ideal candidate building products for carbon storage, as they are mass-produced and conventionally cured with steam. In order to make the process economically feasible, self-concentrating absorption technology was studied to produce low cost CO2 for concrete curing. The compact design of the CO2 chamber and low cost carbon capture technology should result in a net process cost of less than $10 per ton of CO2 stored. The proposed research examined the possibility of achieving a cost-effective, high-performance concrete manufacturing process through a prototype production using specially designed chambers, called CO2 claves, to replace steam kilns and implement forced-diffusion technology to maximize carbon uptake at minimal process costs.

This project will result in a detailed database of flame speed and kinetic information, and demonstrate the validity of a comprehensive kinetics model that can predict NOx formation, flame speed, and ignition behavior in the presence of high levels of dilution and minor levels of likely contaminants. These results will lead to deeper understanding of the turbulent flame speed behavior and NOx-formation kinetics of HHC fuels for IGCC applications.

The main objectives for this project are: demonstrating Accelergy's integrated carbon to liquids technology (ICTL) utilizing Montana bituminous coal and indigenous biomass feeds; develop engineering and econometric models on conversion of coal and biomass/algae to liquids using a Montana planning basis; and implement a comprehensive education and training program to prepare the local community for future jobs in the ICTL arena.

This project provided rigorous estimates of the carbon storage potential of mafic and ultramafic rocks through the process of in-situ mineral carbonation. Mafic and ultramafic rocks contain low levels of silica and high levels of calcium-rich minerals that react with CO2 to form solid carbonate minerals, thus permanently isolating it from the atmosphere. The project involved two related, interdisciplinary parts: (1) geochemical experiments and modeling on individual minerals and rock assemblages to determine kinetics and thermodynamics of the main mineral carbonation reactions, and (2) geomechanical experiments and modeling to elucidate processes accompanying the carbonation reactions, such as flow and deformation, which can significantly alter the effective reaction rates in actual rock formations.

Montana State University developed a biomineralization-based technology for sealing preferential flow pathways in the vicinity of injection wells. The engineered biomineralization process produces biofilm and mineral deposits that reduce the permeability of geologic media while modifying the geochemistry of brines to enhance CO2 solubility and mineral precipitation. This process can be targeted to the geologic media surrounding carbon storage injection wells to provide long-term sealing of preferential CO2 leakage pathways. The project had three main objectives: (1) construct and test a mesoscale high pressure rock test system (HPRTS); (2) develop biomineralization seal experimental protocol; and (3) create biomineralization seals in different rock types to simulate different potential field conditions.

Gas Technology Institute, partnering with PoroGen Corporation and Aker Process Systems, proposes to develop cost-effective separation technology for CO2 capture from flue gases based on a combination of absorption and hollow fiber membrane technologies. In a three-phase effort, they plan to develop a highly chemically inert and temperature stable PEEK hollow fiber membrane optimized for CO2 capture in a membrane contactor, an integrated membrane absorber and desorber, and an energy efficient process for CO2 recovery from the flue gas. The contactor can be utilized for removal of numerous other gas pollutants such as NOx and SOx, for separation of CO2 from hydrogen in refinery streams, and for separation of CO2 from natural gas (natural gas sweetening).

Columbia University researchers are testing and evaluating carbon-14 (14C) as a reactive tracer to assess CO2 transport in a basaltic storage reservoir. Evaluation of mineral trapping through carbonation is also being completed. Studies are conducted at the CarbFix CO2 pilot injection site in Iceland. The study evaluated 14C in combination with trifluormethylsulphur pentafluoride (SF5CF3) as a conservative tracer to monitor the CO2 transport in a storage reservoir. In addition, the study is helping to verify in situ mineral carbonation by performing laboratory analyses on retrieved fluid and rock samples. Researchers obtained fluid and rock samples from the CarbFix CO2 pilot injection site in Iceland where the injected CO2 is labeled with 14C. Samples were analyzed to study the extent of mineral carbonation in a basaltic storage reservoir. Carbon-14 in combination with d13C, total dissolved carbonate and SF5CF3 analyses are being used to quantify carbonation and to estimate in situ reaction rates for the basalt reservoir. The 14C, d13C, and the total dissolved or precipitated carbon data from the fluid and rock samples were used to estimate a carbon mass balance for the CarbFix site. The study drilled a 600 meter borehole and retrieved core and samples to also verify the mineral carbonation.

Advancements in hydrogen (H2) membrane separation are critical to allow the development of a viable H2 economy based on coal/biomass processing with CO2 capture. To reach the technology targets set by the Department of Energy (DOE), United Technologies Research Center (UTRC), in collaboration with Power+Energy, Inc. (P+E) and the Energy and Environmental Research Center at the University of North Dakota (EERC), proposes to demonstrate the membrane-based separation of H2 from coal-derived syngas at the pre-engineering/pilot scale using an improved Palladium (Pd) based membrane technology.

Western Research Institute proposes to build and test several pilot scale hydrogen separation devices for use in a gasification product stream. The outcome of the project will be a demonstration of manufacturing practices in addition to the delivery of the engineering for a hydrogen production system ready for testing at large scale.

GE Global Research, GE Energy, and the University of Pennsylvania will model creep-fatigue-environment interactions in steam turbine rotor materials for advanced ultra supercritical coal power plants. The work will demonstrate computational algorithms for alloy property predictions and to determine and model key mechanisms contributing to the damages of creep-fatigue-environment interactions.

This project focuses on the computational development of a new class of materials called MAX phases, or Mn 1AXn (M = a transition metal, A = Al, X = C or N). The MAX phases are layered transition metal carbides or nitrides with the rare combination of metallic and ceramic properties. Due to their unique structural arrangements and directional bonding (both covalent and ionic) these thermodynamically stable alloys possess some of the most desirable properties such as damage-resistance, oxidation resistance, excellent thermal and electric conductivity, machinability, and fully reversible dislocation-based deformation. These properties can be explored in the search for new phases and composites that can meet performance goals set by DOE for applications in the next generation of fossil energy power systems.

The objectives of this project are to develop, demonstrate, and validate computational capabilities for predictive analysis of interactions at the grain boundary of refractory alloys. The simulation capabilities will include Quantum Mechanics (QM) based ReaxFF potentials integrated into an open-source Molecular Dynamic (MD) code including the Large-scale Atomic/Molecular Massively Parallel Simulator (LAMMPS-MD) simulator developed by Sandia National Laboratories.

The objectives of the proposed research are to: (1) develop and integrate modern computational tools and algorithms required to assist in the optimization of creep properties of high-temperature alloys for fossil-energy applications; and (2) achieve a fundamental understanding of the processing-microstructure-property-performance links underlying the creep behavior of novel ferritic superalloys strengthened by B2 and/or L21 intermetallics. In the first objective, researchers seek to integrate tools and methods associated with predictive first-principles calculations, computational thermodynamic and kinetic modeling, and meso-scale dislocation-dynamics simulations. In the second objective, some of the computational results we will be validated by measuring selected microstructural attributes in representative model ferritic superalloys with a hierarchical microstructure, where the Fe-based disordered matrix is strengthened by one or two ordered precipitate(s).

The principal objective of this project was to determine the influence of diagenetic and structural features at the reservoir/caprock interface on transmission of CO2 into and through the caprock. The study focused mainly on the influence of deformation structures and fractures on fluid flow. The project team investigated interfaces in three different reservoir/seal pairs. The first stage of the project involved a brief field campaign to perform basic descriptions of the interfaces and conduct detailed sampling. The second stage involved laboratory analysis of the samples to describe their petrographic, geochemical, mechanical, and petrophysical properties. Finally, the descriptive information acquired in the first two steps was used as input data for a detailed coupled thermal hydrologic mechanical chemical modeling investigation of the implication for transmission across the storage zone/caprock interface. Some of the findings of this study are that differences in permeability at the reservoir-caprock interface caused by deformation bands and fractures have a large impact on fluid flow and that seals have the capacity to store large quantities of CO2 if permeable fractures terminate below the top of the seal.

URS Group, in collaboration with the University of Texas and Trimeric Corporation, will investigate the use of concentrated piperazine (PZ) as a solvent for absorbing CO2 from coal-fired power plant flue gas while employing a novel, high-temperature, two-stage flash regeneration design. The project objectives are to quantify and validate the robustness of concentrated PZ in an integrated absorption/stripping system with solvent regeneration at 150°C; optimize the equipment design and energy performance of the two-stage flash system; and identify and resolve other potential operational and design issues including process control, corrosion, foaming, and solids precipitation. The project results will be used to evaluate the technical and economic feasibility of a full-scale implementation of this process. Previous evaluations of concentrated PZ have indicated greater than 90% capture with significant progress toward the Department of Energy (DOE) cost of electricity goal. This project continues the development of the PZ-based CO2 absorption process through field tests at the University of Texas' Separations Research Program plant and DOE's National Carbon Capture Center.

Collaborators at the University of Illinois at Urbana-Champaign and Energy Commercialization, LLC will investigate the use of a carbonate salt (potassium or sodium carbonate) as a solvent for absorption-based, post-combustion CO2 capture. A preliminary techno-economic evaluation shows that energy use with the Hot Carbonate Absorption Process (CAP) is about half that of its monoethanolamine (MEA) counterpart. The Hot-CAP process integrates a high temperature (70-80 degrees Celsius) CO2 absorption column, a slurry-based high pressure (up to 40 atm) CO2 stripping column, a crystallization unit to separate bicarbonate crystals and recover the carbonate solvent, and a recovery unit for the calcium sulfate byproduct of SO2 removal. The research team will perform a proof-of-concept study aimed at generating process engineering and scale-up data to help advance Hot-CAP technology to the pilot-scale demonstration level within three years.

The CREST research team will optimize catalysts used for the conversion of southwestern lignite into synthetic crude oil that can be shipped to nearby Texas refineries and power plants for development of transportation fuels and power generation. Research will also be undertaken to convert any potential by-products of this process such as CO2 to useful chemicals and gases which may be recycled and used as feedstock to the synthetic fuel process. The overall project is divided into three tasks including a management task outlined in the following document.

The objective of this two-year bench-scale project is to develop a cost-effective hybrid system for CO2 capture based on the performance achieved by the sub-ambient temperature operation of the Air Liquide hollow fiber membrane. The membrane will be coupled with cryogenic processing technology in a closed-loop test system that will verify the effect of possible contaminants, such as SOx, NOx and water, on membrane performance at levels relevant to coal-fired power plants. Experimental results will be used to refine the integrated process simulation and to design a slipstream facility.

The objective of this study was to develop a reservoir-assessment tool based on novel and robust borehole seismic technology that can generate ultra-high resolution P and S wave images for detailed characterization and precise monitoring of CO2 storage sites. Paulsson investigators built and tested a prototype downhole seismic system capable of deploying a thousand 3C downhole receivers using fiber optic sensor technology deployed on drill pipe. The system was tested at a CO2 storage site. There are three primary components of a downhole seismic system: (1) the seismic sensor, (2) the deployment system, and (3) the surface electronics and recording system. The planned approach for the sensor involved designing a high-temperature fiber optic receiver. For a deployment system, a small diameter, high strength drill pipe using offshore drill pipe manufacturing technology was used. The drill pipe was used as the backbone for the high-temperature deployment system and power is supplied through the tubing to clamp the receiver pods to the borehole wall. The strain on the fiber was recorded, analyzed, and transformed into a seismic record using an interferometric technique with all electronics and instruments placed at the surface.

The project made accurate predictions for the trapping of injected mixed supercritical (sc)CO2, in the deep saline aquifer of the Rock Springs Uplift (RSU) in Southwest Wyoming. Such predictions were based on new, state-of-the-art experimental measurements of relevant flow functions that were used in a recently developed, high-performance, high-resolution simulation tool. Results of state-of-the-art laboratory experiments using core samples from the RSU were used in a physically-based dynamic core-scale pore network model that led to improved understanding of mixed scCO2 trapping mechanisms, This, in turn, allowed the identification of pore-level flow conditions under which permanent capillary trapping can be maximized, which were subsequently communicated to a high performance simulation tool. This tool allowed for geomechanical deformation of the surrounding formations, equilibrium calculations for mixed scCO2, water, and salt, and was used for uncertainty quantification using geological models.

The overall objective of this project is to obtain the first rigorous assessment of the amount and extent of local capillary trapping expected to occur in typical storage formations. The University of Texas Austin is gathering variogram models typical of CO2 storage formations and generating a large number of geostatistical realizations of permeability from these models. The realizations are being populated with key petrophysical properties using crossproperty correlations and the spatial properties of the resulting model formations are being analyzed to determine the potential for local capillary trapping. The emplacement and buoyancy-driven migration of CO2 and the onset of a leakage path in the overlying seal is being simulated and the simulation was analyzed to determine the extent of filling of the local capillary traps and the degree of immobilization within them. Final-scale CO2 saturation distributions were extracted from the simulations and bench-scale buoyant displacements in heterogeneous 2D sand packs were performed.

The University of Texas at Austin (UT Austin) developed a prototype modular computational approach for monitoring the location of the CO2 plume as it moves through the subsurface during the injection process—the period when the CO2 is pumped through an injection well into the targeted rock formation. The approach utilized project injection rate and pressure data as a basis for the modeling input. This enabled modeling and monitoring capabilities at negligible incremental cost because injection rate and pressure data is recorded for operational reasons in every carbon storage project. A goal of the modular computational approach is to take advantage of the inherent flexibility it provides, allowing for other types of data, such as surface deflection or seismic imaging, to be easily included with the rate/pressure data to reduce the uncertainty of the inferred plume location.

On August 5, 2010, Secretary Chu announced DOE's intent to award $1 billion in Recovery Act funding to the Ameren Energy Resources, Babcock & Wilcox (B&W), and Air Liquide Process & Construction, Inc. (AL), and the FutureGen Industrial Alliance (FGA), to build FutureGen 2.0. FutureGen 2.0 will help ensure that the United States remains competitive in a carbon constrained economy, creating jobs while reducing greenhouse gas pollution. FutureGen 2.0 is expected to be the world's first, commercial-scale, oxy-combustion power plant, and will help to open up the over $300 billion market for coal unit repowering and position the nation's electric power sector to utilize technologies that could capture and sequester significant amounts of CO2. To ensure timely implementation, a two track approach was devised where Ameren, B&W and AL will repower the Ameren power unit with oxy-combustion technology and capture and compress the CO2 for transport while the FGA will manage the process of CO2 transportation, storage as well as development of visitor and educational facilities.

Wind tunnel facilities at The Pennsylvania State University (Penn State) and University of Texas at Austin (UT) have been specifically designed to simulate film cooling of turbine vanes, blades, and endwalls. These facilities incorporate equipment that simulates the deposition of contaminants in the turbine by using molten wax particles to simulate the molten contaminant particles that occur at actual engine conditions. The wax particles used in the test facilities are sized appropriately to simulate the inertial behavior of particles that exist in engine conditions. The use of wax also allows for the simulation of the liquid-to-solid phase change that is essential to the primary deposition mechanism. UT will be focusing on the performance of shallow trench film cooling configurations for various positions on the suction and pressure sides of a simulated vane with active deposition. Meanwhile, Penn State will be investigating the effect of active deposition on various endwall cooling configurations. Preliminary results show that deposition could be simulated dynamically using wax and that the effects of deposition could be quantified using infrared thermography. New endwall and vane surface film cooling configurations will be developed to minimize deposition and maximize cooling performance under contaminated conditions.

ION Engineering, LLC and its subcontractors will conduct bench-scale testing of an amine-based solvent that employs an ionic liquid instead of water as the physical solvent, greatly reducing the regeneration energy while lowering process water usage. In addition to a 60 percent reduction in regeneration energy requirement, an ionic liquid-amine solvent mixture offers higher CO2 working capacity, reduced corrosion, reduced solvent loss, and other benefits when compared to conventional aqueous amine solvents.

Praxair is conducting research to develop hydrogen transport membrane (HTM) technology to separate carbon dioxide (CO2) and hydrogen (H2) in coal-derived syngas for IGCC applications. The project team has fabricated palladium based membranes and measured hydrogen fluxes as a function of pressure, temperature, and membrane preparation conditions. Membranes are a commercially-available technology in the chemical industry for CO2 removal and H2 purification. There is, however, no commercial application of membrane processes that aims at CO2 capture for IGCC syngas. Due to the modular nature of the membrane process, the design does not exhibit economy of scale—the cost of the system will increase linearly as the plant system scale increases making the use of commercially available membranes, for an IGCC power plant, cost prohibitive. For a membrane process to be a viable CO2 capture technology for IGCC applications, a better overall performance is required, including higher permeability, higher selectivity, and lower membrane cost.

The project is an international collaboration which brings together Canada, the U.S., the European Community, and Japan, as well as numerous other industrial and government sponsors. The research program integrates studies with the $2 billion commercial EOR and storage operations of Cenovus Energy and Apache at the Weyburn and Midale oil fields in the Williston Basin, Saskatchewan. The project is being completed through several phases with an overall goal of enhancing the knowledge base and understanding of CO2 geologic storage conducted with Enhanced Oil Recovery (EOR) operations. CO2 EOR and storage operations are studied in the Weyburn and Midale oil fields to understand controlling conditions and processes such as site suitability, reservoir capacity, reactive transport, storage integrity, wellbore performance, risk assessment, and effective monitoring and validation techniques.

Akermin proposes the development and demonstration of a bench scale level reactor with the ability to capture up to 90% of CO2 from a simulated flue gas using a solvent with significantly lower regeneration energy at rates comparable to the solvent monoethanolamine (MEA). Over the course of the project, Akermin will identify the most suitable strains of carbonic anhydrase for carbon capture under industrial conditions, optimize a micellar polymer structure for enzyme immobilization and interface with contactor systems, and demonstrate its efficacy in a bench scale unit capable of processing up to 500 standard liters of gas per minute.

Parker aims to advance its micro-mixing injector platform, which has already demonstrated low NOx emissions, to improve combustion operability, in particular by attenuating combustion dynamics. This will be accomplished by developing and implementing a high-bandwidth piezo valve with the capability to adaptively modulate fuel flow to the premixer.

West Virginia University (WVU) will identify the fundamental mechanisms of carbon deposition and coal contaminant poisoning of Solid Oxide Fuel Cells (SOFCs) and develop novel materials to minimize the impact of these contaminants on fuel cell performance. The effects of trace contaminants found in coal will be characterized, and remedies for any adverse effects proposed. The research will focus on the modeling, manufacture, and testing of SOFCs fueled by simulated coal gas.

The overall objective of the proposed 36-month effort is to develop the models needed to accurately predict conversion rates of coal/biomass mixtures to synthesis gas (syngas) under conditions relevant to a commercially-available coal gasification system configured to co-produce electric power and liquid fuels. The scope of work involves testing coal/biomass mixtures in our entrained flow reactors and pressurized thermogravimetric analyzer in order to obtain the data needed to develop a model that accurately predicts char mass loss rates in the types of environments established in commercial entrained flow gasifiers.

Auburn will attempt to provide a fundamental understanding of how solid oxide fuel cell interconnects are protected from oxidation and performance degradation by coatings. This project will help to explain why some coatings of particular compositions work particularly well while others do not. It is expected that the project will result in information which will guide further coating and interconnect steel development.

The scope of this Small Business Innovative Research (SBIR) Program Phase III project includes the design, analysis, fabrication, assembly, installation, and testing of prototype spar-shell turbine airfoils and associated hardware, culminating in the validation of performance and functionality in a commercial gas turbine.

Gas Technology Institute is developing a reliable, practical, and cost effective means to monitor coal gasifier flame characteristics using a modified version of an optical flame sensor already under development.

The effort to make ultra-clean gasification commercially competitive includes increasing the life of gasifier injectors (which feed fuel into the gasifier). As the injectors age and wear out, the flames they produce change. Monitoring these flames will allow plant operators to more accurately predict when they have to be changed, reducing gasifier maintenance costs.

The proposed effort will advance the performance of refractory metals by integration of high temperature coating processes uniquely by means of modeling and experimental verifications in a focused, staged development. The ultimate goal of the proposed study will be to deliver the key enabling coating technology for at least a 400 degrees Celsius (°C) increase of the metal operating temperature from 1200°C to 1600°C.

This research will provide a systematic evaluation of flameholding tendencies in various combustor fuel/air premixer passage geometries. This evaluation will be completed for different fuel types (including high hydrogen content [HHC] fuels) at operating conditions (temperature, pressure, etc.) typical of those encountered in industrial-scale turbines. The observations made relative to flameholding tendencies will be analyzed and used to develop design guides that can be used to infer when flameholding will occur as a function of the parameters studied. The high pressures and temperatures required to simulate the environment of a premixing passage for a natural gas-fired gas turbine will be generated at the University of California, Irvine Combustion Lab high pressure facility. The facility is capable of generating a preheated airflow at temperatures up to 1200 degrees Fahrenheit, pressures exceeding ten atmospheres, and a maximum flow rate that exceeds three pounds per second. To provide the planned conditions, a modular test apparatus will be used.

This project will focus on development of advanced thermal based coatings (TBC) to improve the performance of coatings for Nb-based, high-temperature alloys. A computer model to predict the properties of novel thermal barrier coatings will be developed and validated. Concurrent laboratory testing will be used to validate predictions of the model.

The particulate deposition model developed by The Ohio State University (OSU) in prior University Turbine Systems Research (UTSR) work will be modified to better account for the fundamental physics of particle impact and sticking, including particle and surface properties. Experimental data from OSU's Turbine Reacting Flow Facility (TuRFR) deposition cascade facility will be used to validate the revised model. The TuRFR facility will be modified to provide for the generation of inlet temperature profile non-uniformities (hot streaks), which will be tracked through the turbine nozzle passage using surface temperature infrared imagery and exit plane temperature measurements. Hot streak evolution and the effect of the hot streaks on deposition will be evaluated. Film cooling will then be added to both the experiments and the computation to evaluate its effect on hot streak migration and deposition. Finally, the model's ability to track hot streak migration will be exercised on a full turbine stage (vane and rotor) using data acquired in the OSU Gas Turbine Laboratory transient turbine test rig. The model will also be used to predict deposition in the rotating configuration, although there will be no experimental validation of deposition in the rotating frame.

The proposed metal chromium-aluminum-yttrium (MCrAlY; where M = nickel [Ni], cobalt [Co] or a mixture of Ni and Co) bond coats will be synthesized via an electrolytic codeposition process, followed by a post-plating heat treatment. In contrast to traditional electro-codeposition processes where sulfate or sulfamate bath is used for Ni/Co deposition, a sulfur-free electrolyte will be employed to control the impurity levels in the MCrAlY coatings. The reduced sulfur (S) levels will be expected to improve oxide scale adhesion. The amounts of Cr, Al, and particularly the Y reservoir, in the MCrAlY bond coat will be optimized to extend the lifetime of the thermal barrier coating (TBC) system. Reactive elements such as Y hafnium (Hf) or Y zirconium (Zr) will be co-doped into the MCrAlY coatings by modifying the composition of the CrAlY alloy powder. The composition of the CrAlY alloy (where equals Hf or Zr, etc.) will be carefully designed, based on the literature data for model MCrAlY alloys and other types of MCrAlY coatings. Other parameters of the electrolytic codeposition process will be systematically studied using a design-of-experiment approach to provide a fundamental understanding of their synergistic effects and to optimize the coating composition and microstructure.

This project is intended to investigate and deliver high-temperature oxygen sensors based on pure and doped gallium oxide (Ga2O3) nanostructures operating at 800 °C and above in a corrosive atmosphere. The impetus is designing the Ga2O3-based nanostructured materials for application as oxygen sensors operating at extremely high temperatures in fossil fuel energy systems with a demonstrated reliability, stability and without any interference from other pollutants/emissions.

This Purdue University project is a detailed investigation of the structure and dynamics of fuel jets injected into a subsonic oxidizing crossflow in order to enhance the fundamental level of understanding of these important flows and to provide a validation database for comparison with detailed numerical models of the reacting jets in crossflow (RJIC). Advanced laser diagnostics, including high-speed particle imaging velocimetry (PIV), high-speed planar laser-induced fluorescence (PLIF), and coherent anti-Stokes Raman scattering (CARS) will be used to probe the flow fields in a high-pressure gas turbine combustion facility. PIV and planar laser induced fluorescence of OH radicals (OH PLIF) will be used to visualize fuel/air mixing and combustion at data rates of 5-10 kilohertz (kHz). One kHz CARS will be employed for temperature measurements using femtosecond lasers. The combustion facility will utilize three different fuels: a natural gas (NG) baseline and two high-hydrogen-content (HHC) fuels. Accurate high-resolution spatial and temporal measurements of the resulting turbulent flame structures will provide improved understanding of the complex processes of fuel/air mixing and turbulence-chemistry interaction with attendant impact on operability when using HHC fuels. Additionally, the representative crossflow will be forced into stationary and oscillatory conditions to simulate an unstable condition. The enhanced mixing and combustion of the fuel jet will be measured to quantify the relationship between the unsteady combustion field and the forced oscillatory field. The benchmark quality data sets resulting from these experiments will include comprehensive measurements of mean and fluctuating components of velocity, temperature, and species at high pressure and with crossflow conditions representative of modern gas turbine engines with practical applications within the turbine industry.

The proposed work at the University of Texas aims to develop large eddy simulation (LES) models for simulating high hydrogen content (HHC) gas turbine combustion, with specific focus on premixing and flashback dynamics. The project is divided into three components: (1) LES model development using direct numerical simulation (DNS) and canonical experimental data, (2) targeted experimental studies to produce high quality mixing and flashback dynamics under engine relevant conditions, and (3) validation of LES models using a validation pyramid approach and transfer of models to industry using an open source platform.

The main goal of the project is to quantify the uncertainty associated with kinetic-theory predictions of the clustering instabilities present in high-velocity gas-solid flows. There are two major objectives. The first is to generate benchmark data with an eye toward determining the relative importance of the physical mechanisms that give rise to the instabilities. Although it has been established previously that inelastic collisions and gas-phase effects can independently lead to instabilities in granular and gas-solid flows, their relative importance has not been examined, nor has the expected important effect of friction. The second objective is to apply kinetic-theory (continuum) models, with no adjustable parameters, to the same flow geometries used for the benchmark data. Kinetic-theory models have been shown to predict such instabilities, though previous validation work, such as snapshots and/or movies of particle clusters, is largely qualitative in nature.

This project will implement and validate a new granular stress model in Multiphase Flow with Interphase eXchanges (MFIX) while continuing to improve the model to capture more complex flow behavior. The proposed work consists of the following major goals. Goal 1: Implement in MFIX, the steady shear rheological model developed recently by the PI group; perform MFIX simulations of various test problems such as hopper, chute, and Couette flows using this rheological model and no-slip and partial slip boundary conditions already available in MFIX; and compare against experimental and discrete element method (DEM) simulation data. Goal 2: Develop improved wall boundary conditions for the particle phase that can be applied in all three regimes of flow and implement them in MFIX. Examine the effect of refined boundary conditions on flow characteristics in the test problems mentioned in Goal 1. Goal 3: Further develop the rheological model to allow for dynamic evolution of the stresses, make appropriate modifications to the MFIX implementation, and conduct appropriate validation tests.

This project's objective is to develop novel sensors and refractory measurements and assessment methods that can provide real time measurement of refractory temperature, thickness, and change in material properties.

The goal of this project is to develop cost-effective sensing technologies able to function in harsh, high-temperature operating environments. SUNY investigators intend to develop a photo-detector and a chemical sensor tailored to emissions of interest that will sense a passive light source with sufficient energy in the selected wavelength.

This project will identify the most promising compositions of ferroelectric materials that can be used to make highly efficient thermoelectric devices for waste heat recovery in coal fired power and industrial plants. Combinatorial methods will be used to rapidly screen a broad composition range with high Curie temperatures, followed by an investigation of the thermoelectric properties. Processing approaches to making the materials will be also developed.

The goal of this project is to develop and validate for multiphase gas-solids flow simulations, a non-intrusive uncertainty quantification (UQ) procedure based on polynomial chaos methodology together with a quadrature-based reconstruction of the multivariate probability density function required by the approach, and to implement the procedure as a new algorithm in the NETL Multiphase Flow with Interphase eXchanges (MFIX) multi-phase flow simulation package. The new UQ procedure will first be tested and validated on gas-particle flow problems for which analytical or simple algebraic solutions exist. The procedure will then be installed in MFIX and tested on two (2) complex gas-solid flow scenarios that represent different gas-solids flow regimes.

This project will develop a new fundamental drag model for solid-gas flows using the direct numerical simulation (DNS) method. The new model will consider the effects of particle rotation on the hydrodynamics of gas-solid flows.

The University of Central Florida will develop an accurate and robust wireless passive high-temperature sensor for in situ measurement of strains inside turbine engines in coal-based power generation systems.

This University of Pittsburgh project will determine the degradation mechanisms of current state-of-the-art thermal barrier coating (TBC) in environments comprised of particulate matter and gas mixtures which are representative of gas turbines using coal-derived synthesis gas (syngas). The observed degradation processes will be used to guide the development of improved coatings for hot section components in the potentially harsh gas turbine environments in which fuels derived from coal and even perhaps biomass are burned. The unresolved complexities associated with TBC durability include enhanced attack of yttria-stabilized zirconia (YSZ) top coating by chemical reaction, physical damage of the topcoat by molten deposit penetration, and accelerated bond coat corrosion. This work is investigating how the interaction between the ash and oxidants affect TBC degradation by using lab-scale testing. Important outcomes from this study will include understanding TBC degradation; modeling integrated gasification combined cycle (IGCC) environments to develop better coatings; and extending the service life of TBCs by mitigating degradation. This research is using the high-temperature corrosion testing facilities at the University of Pittsburgh. The deposits currently being used are based on fly ash, and accordingly, consist of calcium oxide (CaO), aluminum oxide (Al2O3), silicon dioxide (SiO2) and iron oxides (FeOx). Additions of potassium sulfate (K2SO4) and iron sulfide (FeS) are used to simulate other ash constituents. The tests are being conducted on two different TBC system types provided by Praxair Surface Technologies (PST) of Indianapolis, Indiana. PST will also conduct thermal gradient tests for assessing TBC durability with and without deposits. Both exposed and unexposed test samples are being extensively characterized using the suite of capabilities available at the University of Pittsburgh.

This University of North Dakota project is designed to refine the evaporative metal bonding (EMB) method, then apply the refinements to bonding a layer of corrosion- and spallation-resistant alloy, advanced powder metallurgy technology (APMT) to turbine parts composed of two nickel superalloy compositions and test the parts to determine if lifetimes have been increased. The work involves measurement of the temperature-dependent diffusion rates of zinc, the bonding metal used in the EMB process. The component superalloys of interest are CM247LC®, and Rene 80. The corrosion and spallation resistant super alloy layer is APMT. This information will help the University of North Dakota Energy & Environmental Research Center (EERC)-led project team better design the heat treatments needed to create the bonds between the super-alloys and the APMT plating and assure that the zinc completely diffuses out of the turbine components created. The team will also model force distributions in the clamped structures being plated with APMT to assure that the compressive force used to hold the APMT and superalloys together during bonding is adequately distributed over the surfaces being joined. This modeling capability will allow the team to better design the clamping fixtures and force distribution plates (buffers) that will be used to bond plates of the APMT to more complex superalloy turbine parts. To determine the appropriate conditions for corrosion testing of the bonded parts in simulated turbine conditions, the team will measure trace constituents in combusted syngas produced in the EERC entrained-flow gasifier. This will consist of combusting a slipstream of cleaned coal derived synthesis gas (syngas) produced from the gasifier, quenching the combusted gas with nitrogen, and collecting the submicron particulates on Nuclepore surface filters and gaseous constituents in activated carbon, zeolite traps, or gas impingers. After determining the best heat treatment and clamping methods, the team will bond plates of APMT to the surface of superalloy test samples (buttons) and turbine parts provided by Siemens. Siemens will also apply thermal barrier coatings (TBCs) to some of the bonded parts and evaluate them. The EERC will perform laboratory hot corrosion tests simulating post-combustor turbine gas compositions, including relevant trace species defined in pilot-scale testing used to bond plates of the APMT to more complex superalloy turbine parts.

The University of Connecticut, in cooperation with Pratt & Whitney and Siemens Energy, will use a novel solution precursor plasma spray (SPPS) process to deposit low thermal conductivity, high durability yttria stabilized zirconia (YSZ) thermal barrier coatings (TBCs) and to utilize surface protective layers (SPLs) to provide high temperature contaminant resistance and increased surface temperature capability, while minimizing the use of rare earth elements. The SPPS process provides a unique TBC microstructure that consists of through-thickness vertical cracks for strain tolerance, ultra-fine splats for spallation crack resistance, and the ability to produce very low thermal conductivities. The low thermal conductivities, or low-K (with K representing heat conductivity), will result from planar arrays of fine porosity called inter-pass boundaries (IPBs) and the ability to vary porosity content over wide ranges. The IPBs are generic conductivity lowering features that can be implemented for any TBC. Pratt & Whitney and Siemens Energy will contribute valuable specimens and will test the down-selected low-K TBCs. The low-K YSZ TBC structure will be created using the SPPS process. Taguchi methods for design of experiments will be used to systematically determine the deposition parameters to minimize the thermal conductivity. Cyclic durability tests of the low-K TBC will be conducted to verify that the excellent durability of the SPPS TBC is preserved. A protective surface layer of gadolinium-zirconium will be added to the low-K YSZ TBC to increase the maximum allowable surface temperature by at least 100 degrees Celsius (°C) and improve its calcium-magnesium-alumina-silicate (CMAS) resistance, while minimizing the heavy use of rare earth elements. This improved contaminant resistance will be verified by testing in CMAS and moisture. Contaminant resistance will be further enhanced by employing two novel approaches, one using aluminum-titanium additions to the YSZ, and the other by deliberately adding calcium sulfate, shown to block CMAS when deposited by natural processes in service engines. The spallation failure mechanisms of the low-K TBC will be defined to provide guidance for subsequent improvements and a sound basis for life prediction methodologies.

Battelle Pacific Northwest Division, Fluor Corporation, and Queen's University have teamed together to develop a new CO2-capture technology for treating post-combustion emissions. This new process couples the unique attributes of non-aqueous, switchable organic solvents (CO2 binding organic liquids - CO2BOLs) with the newly discovered polarity-swing-assisted regeneration (PSAR) process. This process requires significantly lower temperatures and energies for CO2 separation relative to conventional technology, making significant cost savings possible. Combining the polarity assist with CO2BOLs is estimated to provide more than 42% energy savings over aqueous alkanolamine systems. Further, the low regeneration temperatures of the proposed technology also allow a unique energy integration method that can reduce overall parasitic loads by more than 65% compared to commercial systems.

The main objective of this project is to develop an information theoretic sensing and control framework that encompasses distributed software agents and companion computational algorithms that maximize the collection, transmission, aggregation, and conversion of data to actionable information for monitoring, diagnosis, prognosis and control of advanced power plants.

Linde LLC (Linde), along with BASF and the Electric Power Research Institute, will design, build, and operate a 1 megawatt electrical (MWe) equivalent slipstream pilot plant at the National Carbon Capture Center (NCCC) to further refine a post-combustion capture solvent technology developed by Linde and BASF. The technology incorporates BASF novel amine-based solvent, OASE® blue, along with Linde process and engineering innovations. The post-combustion capture technology offers significant benefits compared to other solvent-based processes with the capability to reduce regeneration energy requirements by using novel solvents that are stable under the coal-fired power plant feed gas conditions. The project objectives are to design and build the 1 MWe pilot plant; conduct parametric testing to confirm that the pilot plant meets the performance targets and to obtain appropriate design information; perform a detailed data analysis to assess and develop the design basis for scale-up; and operate the pilot plant continuously under stable conditions to confirm the solvent stability and key material compatibility. The long-term test results will be used to update a techno-economic analysis for a 550 MWe coal-fired power plant incorporating the novel amine-based post-combustion CO2 capture technology and confirm that it can meet the Department of Energy carbon capture performance goals.

Rice University is investigating a novel solvent-based absorption process for carbon dioxide (CO₂) capture that combines the absorber and desorber columns, separated by a microporous ceramic membrane, into a single integrated unit. This novel capture process uses ceramic foam contactors with complex, highly-interconnected structures for the absorption and desorption of CO₂. The ceramic gas-liquid contactors have favorable characteristics for mass transfer with large geometric surface areas up to ten times that of conventional packing. Additionally, the process will include metal oxide catalysts that enhance CO₂ desorption from amine-based solvents at lower temperatures, resulting in reduced energy consumption and less solvent degradation and evaporation. Commercially available solvents with well-documented performance will be examined. A bench-scale prototype will be developed to implement the complete CO₂ separation process and tests will be conducted to study various aspects of fluid flow in the process. A model will be developed to simulate the two-dimensional fluid flow and optimize the CO₂ capture process. Test results will be used to develop a final techno-economic analysis and identify the most appropriate absorbent as well as optimum operating conditions to minimize capital and operating costs. This analysis will indicate the feasibility of integrating the process into a 550 megawatt electric (MWe) coal-fired power plant.

Blackhorse Energy, LLC is evaluating the early Eocene-aged Wilcox formation located in Livingston Parish, Louisiana. The Wilcox formation is a mature developed oil reservoir (named the Livingston Reservoir) approximately 10,000 feet below ground surface. The depositional environment for this formation is a beach/barrier nearshore marine bar (Figure 1). The reservoir has been undergoing traditional secondary EOR techniques (water flooding) to increase oil production since 1987. This project will utilize tertiary EOR techniques by injecting approximately 52,000 metric tons of supercritical CO2 and CO2 foam (a CO2 based substance that tends to reduce the surface tension of a liquid in which it is dissolved) into the formation to advance the oil recovery process and examine and prove the suitability of South Louisiana geologic formations for large-scale geologic storage of CO2.

This small-scale injection project will use remote time-lapse monitoring to measure, track, and assess how effectively overlying zones contain the injected CO2, determine the physical and geochemical fate of CO2 in the reservoir, and refine the storage resource estimate. Other MVA tools that will be used to monitor the migration of injected CO2 include advanced logging tools and fiber optic technology. Innovative injection well design will test the ability of short-radius, horizontal well technology to increase geologic storage of CO2 in the reservoir by increasing the available injection length within the reservoir. The monitoring and existing field production wells will be leveraged for data gathering to further characterize and understand the Wilcox depositional environment in south
Louisiana.

 

Virginia Tech is evaluating the long-term storage potential of CO2 in coal seams and organic shales by injecting up to 20,000 metric tons of CO2 into these unconventional reservoirs in central Appalachia. This project is designing and implementing characterization, injection, and monitoring activities to test unconventional formations (coal and organic shales) ability to store CO2 economically and safely as well as track the migration of CO2 throughout the injection and post-injection phases. In addition, this research will test the injectivity of CO2 into unmineable coal seams and the potential for enhanced coalbed methane recovery (ECBM) by stressing the coal under continuous CO2 injection for a period of one year.

The scope of this University of Michigan computational effort addresses the development of a fully validated large-eddy simulation (LES)-modeling capability to predict unstable combustion of high hydrogen content (HHC) fuels. To incorporate effects of preferential diffusion, pressure variations, and variations in mixture composition, an unsteady flamelet-based LES combustion model will be extended. The integrated LES-validation effort includes (1) an a priori analysis of critical modeling assumptions using a Direct Numerical Simulation (DNS) database of jet-in-cross-flow configurations, and (2) a posteriori model validation in LES application of a swirl-stabilized gas turbine combustor. The LES-combustion model will be used to develop detailed simulations to characterize facility-induced nonidealities in flow-reactor experiments. Effects arising from high-Reynolds number turbulence transition, mixture stratification, and other mechanisms associated with turbulence/ chemistry interaction on the autoignition behavior will be quantified through parametric calculations. The information gained from these efforts will be used to develop a low-order model that can be utilized for chemical-kinetics investigations and for guiding and improving future flow reactor designs in order to reduce facility effects. The experimental effort includes high-pressure measurements of HHC fuel combustion in a dual-swirl gas turbine combustor, development of a comprehensive experimental database for LES model validation by considering stable and unstable gas turbine operating conditions, and obtaining improved understanding about fundamental combustion-physical mechanisms that control flame-holding, liftoff, and flashback for HHC fuels. A range of pressures, HHC fuel compositions, and equivalence ratios will be investigated experimentally.

Novozymes proposes to design, build, and test an integrated bench-scale system that combines the attributes of the bio-renewable enzyme catalyst carbonic anhydrase with low-enthalpy absorption liquids and novel ultrasonically enhanced regeneration for a CO2 capture process with improved efficiency, economics, and sustainability. The application of ultrasonic energy forces dissolved CO2 into gas bubbles, thereby increasing the overall driving force of the solvent regeneration reaction. The technologies are projected to reduce the net parasitic load to a coal-fired power plant by as much as 51% compared to conventional monoethnolamine (MEA) scrubbing technology.

This project will develop and validate new drag force correlations for the case of particle clustering, based on direct numerical simulation of gas-solids flow structures in risers and vertical columns; and validation of the proposed drag law by using the Multiphase Flow with Interphase eXchanges (MFIX) multiphase flow simulation code to compare the experimental data generated in this project with computational results generated by MFIX simulations.

The objective of this project is to scale up and demonstrate a hybrid solid sorbent technology for CO2 capture and separation from coal combustion-derived flue gas. The technology is a novel solid sorbent based on the following ideas: reduction of energy for sorbent regeneration, utilization of novel process chemistry, contactor conditions that minimize sorbent-CO2 heat of reaction and promote fast CO2 capture, and low-cost method of heat management. The project will develop key information for the CACHYSTM process sorbent performance, energy for sorbent regeneration, physical properties of the sorbent, the integration of process components, sizing of equipment, and overall capital and operational cost of the integrated CACHYSTM system.

TDA Research, Inc. (TDA) will work with Babcock & Wilcox, MeadWestvaco Corporation, the University of California-Irvine, the Gas Technology Institute, and the Illinois Clean Coal Institute to develop a low-cost, high-capacity carbon dioxide (CO2) adsorbent and show its technical and economic ability to selectively remove CO2 from coal-fired power plant flue gas. TDA advanced physical adsorbent consists of mesoporous carbon with surface functional groups grafted onto a patented TDA mesoporous carbon support. The sorbent binds CO2 more strongly than common adsorbents, providing the chemical potential needed to remove the CO2, however, because CO2 does not form a true covalent bond with the surface sites, the regeneration can be carried out with a small energy input. The heat input to regenerate the sorbent is only 4.9 kilocalories per mole of CO2, which is much lower than that for chemical absorbents or amine-based solvents. The mesoporous carbon sorbent was previously developed and validated under a DOE-funded project (DE-FE0000469) for pre-combustion CO2 capture. TDA will advance the adsorbent technology by improving the material capabilities and process design, and by conducting an evaluation with a fully-equipped bench-scale prototype unit using coal-fired flue gas to validate the technical viability of the concept. A techno-economic analysis will be performed to estimate the impact of the CO2 capture system on the plant efficiency and cost of electricity.

Virginia Tech will develop a first-of-a-kind technology for remote fiber optic generation and detection of acoustic waves for structural health monitoring. The technology requires no electric power supply at the monitoring site and the detected acoustic signature as well as the additional returned optical signal allow extraction of information about multiple material conditions including temperature, strain, corrosion, and cracking.

This project will exploit the availability of CO2 in a gasification power island for the benefit of IGCC-CCS integrated plants. EPRI will leverage the findings of laboratory tests to support the development and evaluation of mechanical engineering designs of LRC/LCO2 slurry preparation systems, which in turn will be used to develop higher resolution IGCC plant performance and cost models. The project aims to validate that LCO2 can achieve higher solid loading than water slurry, study the design criteria for a LCO2-coal slurry preparation/mixing system that is superior to conventional feed systems, and demonstrate potential plant thermal efficiency improvement over a water-coal slurry-based feed system.

TDA Research, Inc. (TDA) is demonstrating the technical and economic viability of a new Integrated Gasification Combined Cycle (IGCC) power plant designed to efficiently process low-rank coals. The plant uses an integrated carbon dioxide (CO2) scrubber/water gas shift (WGS) catalyst to capture more than 90 percent of the CO2 emissions, while increasing the cost of electricity by less than 10 percent compared to a plant with no carbon capture.

TDA is optimizing the sorbent/catalyst and process design, and assessing the efficacy of the integrated WGS catalyst/CO2 capture system, first in bench-scale experiments and then in a slipstream field demonstration using actual coal-derived synthesis gas. The results will feed into a techno-economic analysis to estimate the impact of the WGS catalyst/CO2 capture system on the thermal efficiency of the plant and the cost of electricity.

This Reaction Engineering International (REI) project will develop a better understanding of ash deposition onto refractory and metal surfaces associated with the syngas cooler used in integrated gasification combined cycle (IGCC) plants that incorporate a two-stage gasifier. Plugging and fouling of syngas coolers will be evaluated and specific mitigation methods validated. The successful completion of this project will result in improved availability and reliability of the syngas cooler and thereby improve the availability of the overall IGCC plant.

This project is conducting a stacked reservoir injection pilot study to further evaluate the feasibility and efficacy of long-term CO2 storage in saline reservoirs and the use of CO2 in enhanced oil recovery (EOR) operations in the Mid-continent. The stacked pilot study will inject up to 70,000 metric tons of CO2, into multiple formations. This includes a maximum of 40,000 metric tons of CO2 into the Lower Arbuckle Group (an extensive saline aquifer) and a maximum of 30,000 metric tons into the overlying oil-bearing dolomite of the Wellington Oilfield. State-of-the art MVA (monitoring, verification, accounting, and assessment) tools and techniques to monitor and visualize the injected CO2 plume and establish best practice methodologies for MVA in shelf clastic and shelf carbonate formations are being conducted. This will help reduce storage risk by documenting the uncertainties related to these specific depositional environments and monitoring techniques. Additionally, simulation initiatives are being used to integrate multiple in situ and ex situ monitoring systems in tandem to track the location of injected CO2.

The InnoSepra process utilizes sorbents with much lower CO2 capture energy requirements compared to competitive processes and has been successfully demonstrated at the lab scale to obtain greater than 99 percent CO2 purity, and more than 90 percent CO2 recovery. The ultimate goals of the project are to confirm the projected performance of the InnoSepra process at the bench scale; provide sufficient data for design of a commercial-scale plant; and provide a high degree of confidence in the applicability, cost effectiveness and practical feasibility of this process. Projections based on detailed engineering evaluations show that the technology can reduce the power consumption for CO2 capture by more than 40 percent, and the capital cost for the CO2 capture equipment by more than 60 percent at commercial scale, resulting in a more than 40 percent reduction in the CO2 capture cost compared to alternate technologies such as amines.

This project will develop and demonstrate the performance of wireless microwave acoustic sensors for temperature and pressure measurement in high temperature environments. Small battery free surface acoustic wave sensors with integrated antennas, comprised of novel materials that are stable in high temperature environments will be embedded or attached to components and/or structures for real time monitoring in conditions up to 1200ºC and 750 psi.

The U.S. has large reserves of low-cost, low-rank coal, but use in IGCC systems is, to a large extent, limited by the capabilities of available coal feed systems. Conventional dry feed systems feed coal through a system of lock hoppers. This approach has high capital, operating, and maintenance costs and poor reliability, issues that are exacerbated as operating pressure increases. Slurry feed systems suffer an efficiency penalty resulting from the need to evaporate and heat the water contained in the high inherent moisture low-rank coals and the additional water added to form a pumpable slurry, thereby reducing efficiency.

Project personnel are preparing comparative techno-economic studies of two IGCC power plant cases: one with and one without advanced dry feed technology. A common basis of design is being developed. For both cost and performance comparisons, the baseline case (without advanced dry feed technology) is being developed using operational data from the Eastman Chemical Company’s Kingsport gasification facility in combination with data from the DOE case study for IGCC using a low-rank coal with 90 percent carbon capture. Advanced dry feed technology, based upon the Posimetric pump currently under development by GE, will be developed to match the proposed plant conditions and configuration, and analyzed to provide comparative performance and cost information to the baseline plant case. The scope of this analysis covers the feed system from the raw coal silo through the gasifier injector.

The University of Kentucky Center for Applied Energy Research, in partnership with the Electric Power Research Institute, Mitsubishi Hitachi Power Systems America, and Smith Management Group, will develop a heat-integrated, pilot-scale, post-combustion carbon dioxide (CO₂) capture system for a coal-fired power plant using an advanced solvent. A two-stage stripping concept will be implemented to increase capture rate in the CO₂ absorber. In addition, a heat-integrated cooling tower system will also be implemented that uses regenerated CO₂ stream waste heat to dry a liquid desiccant for removing moisture from the cooling air. This method decreases the relative humidity of the air, lowering the cooling water temperature and thereby reducing the steam turbine back pressure for efficiency improvement. A 0.7 megawatt electrical (MWe) equivalent slipstream facility will be designed, constructed, and installed at the Kentucky Utilities E.W. Brown Generating Station, located near Harrodsburg, Kentucky for testing the process. Parametric studies and long-term test campaigns will be performed using a conventional MEA solvent and Hitachi’s H3-1 advanced solvent to validate that the use of an advanced solvent results in less energy consumption and corrosion. Through previous testing, the H3-1 solvent has shown several advantages over conventional amine solvents, including a lower heat of regeneration, higher capacity, and less solvent degradation. A technical and economic analysis of the process concept for a 550 MWe power plant will be completed to determine its potential to achieve the Department of Energy target of no more than a 35 percent increase in the cost of electricity while capturing at least 90 percent of the CO₂ released during the combustion of fossil fuels in existing coal-fired power plants.

General Electric (GE) sees opportunity in the global trend for cleaner power production using its IGCC technology. The company believes that power can be economically and cleanly produced from coal through the use of its technologies and desires to utilize its coal gasification and power generation technology expertise to meet this goal. The objective of this 3-year project is to evaluate potential improvement in total installed cost and availability through deployment of a multi-faceted approach encompassing technology evaluation, constructability assessment, and design methodology. Eastman Chemical Company is supporting the GE effort by providing consulting on the evaluation and technology transfer phases of the project. The end result is to reduce the time to technological maturity and enable plants to reach higher values of availability in a shorter period of time at a lower installed cost.

The primary objectives of this project are to develop, fabricate, and test a novel supported amine, polymeric hollow fibers loaded with silica-supported amine adsorbents, specifically adapted for the purpose of CO2 capture. Two key innovations are (1) the fiber is highly loaded with the solid adsorbent to facilitate large CO2 adsorption capacities with a low pressure drop and (2) the inclusion of an impermeable lumen layer in the interior of the fiber to allow cooling (during adsorption) and heating (during desorption) of the fiber from its bore, hence the name rapid Temperature Swing Adsorption (rTSA). The biggest risk is that the fiber will be poisoned too easily therefore requiring costly flue gas cleaning and replacement of the fibers.

At the University of Michigan Rapid Compression Facility (RCF), experiments will be conducted to extend the high-quality, low-uncertainty experimental database of high hydrogen content (HHC) combustion kinetic benchmarks over a range of operating conditions, including pressures (10-25 atmospheres), temperatures (700-1700K), and the effects of dilution with exhaust gases (where uncertainties in third body coefficients become particularly important). Flammability limits and flame/auto-ignition inter-actions will be determined computationally and experimentally. The RCF data will provide rigorous targets for development of accurate, well validated, detailed, and reduced chemical kinetic reaction mechanisms for HHC combustion, including nitrogen oxide (NOx) chemistry.

Air Products and Chemicals will team with the Energy and Environmental Research Center (EERC) at the University of North Dakota, Grand Forks, N.D., to conduct extensive testing using a mobile, two-bed Sour PSA unit fed with North Dakota lignite coal-based syngas streams. Air Products and Chemicals has developed a proprietary alternative that consists of three process steps: Sour Pressure Swing Adsorption (PSA) that separates the desired products from CO2 and H2S, sulfur disposition that can be accomplished in several different modes, and a CO2 polishing and compression step that produces sequestration-ready CO2. In addition to pressure swing, the adsorbent system will be operated in thermal swing adsorption (TSA) mode to determine performance when exposed to syngas derived from lower-rank coal. The results of this testing will be used to generate a high-level pilot process design and to prepare a techno-economic assessment.

The project will test, with a continuous bench-scale system, an aminosilicone CO2 capture solvent developed as part of a previous DOE-funded program. A manufacturing plan for the aminosilicone solvent and price model will be used for optimization, and combined with a rigorous process model and thorough manufacturability analysis for the solvent, will enable a practical technology path to later development at larger scales and commercialization.

GE Global Research, Idaho National Laboratory (INL), Georgia Institute of Technology (Georgia Tech),and Western Research Institute (WRI) propose to develop high performance thin film polymer composite hollow fiber membranes and advanced processes for economical post-combustion carbon dioxide (CO2)capture from pulverized coal flue gas at temperatures typical of existing flue gas cleanup processes. The project will optimize the novel membranes at the bench scale, including tuning the properties of a novel phosphazene polymer in a coating solution and fabricating highly engineered porous hollow fiber supports. The project will also define the processes for coating the fiber support to manufacture ultrathin, defect-free composite hollow fiber membranes. Physical, chemical, and mechanical stability of the materials (individual and composite) towards coal flue gas components will be evaluated using exposure and performance tests. Membrane fouling and cleanability studies will define long term performance module design, technical, and economic feasibility analyses will be conducted to evaluate the overall performance impact of the process on the cost of electricity (COE). Membranes based on coupling this novel selective material (phosphazene-based polymer) with an engineered hollow fiber support have the potential to capture greater than 90% of the CO2 in flue gas with less than 35% increase in COE, which would achieve the DOE performance criteria.

The project will identify piperazine (PZ) blends that will improve overall solvent and system performance. Recent testing at B&W indicates that blends of concentrated PZ with other organic compounds perform substantially better than PZ itself. Goals include improving system operability and reliability, minimizing environmental impacts, reducing corrosion potential in the system, and maximizing solvent durability. The solvent program will make use of B&W's existing laboratory, bench, and lab-pilot facilities, and a new bench-scale continuous solvent test apparatus will be constructed to characterize solvent degradation.

Research Triangle Institute (RTI), in collaboration with its partners, will develop and evaluate an advanced solid sorbent-based CO2 capture process with the potential to substantially reduce the parasitic energy requirement and costs associated with capturing CO2 from coal-fired flue gas compared to conventional aqueous amine CO2 scrubbing. A promising molecular basket sorbent (MBS) from Pennsylvania State University (PSU) will be combined with RTI circulating, fluidized, moving-bed reactor (FMBR) process design concept and evaluated at bench scale on simulated coal-fired flue gas to validate the feasibility of the process. The MBS comprises a CO2-philic polymer, polyethyleneimine (PEI), loaded onto high surface area nanoporous materials. The sorbent has shown high CO2 loading capacity and thermal properties that could greatly reduce parasitic power requirements for CO2 capture. The cost-effective circulating FMBR design offers superior gas-solid heat and mass transfer characteristics. Key objectives for this project are the optimization and production scale-up of advanced MBS materials in fluidizable form and the development of an associated fluidized-bed process technology. The data obtained during bench-scale testing of the MBS-based CO2 capture process will be used to prepare a design for a full-scale unit and to conduct technical, economic, and environmental analyses.

This project located at the Colorado Springs Drake #7 power plant will design, construct, and test a patented NeuStream absorber. The absorber will employ nozzle technology proven during a recently completed 20 MW NeuStream-S flue gas desulfurization pilot project, and an advanced solvent that efficiently captures CO2. This absorber technology is applicable to a variety of solvents and can be retrofitted to existing pulverized coal power plants with reduced cost and footprint. Because of the modularity of the NeuStream technology, it can be rapidly scaled to larger size systems and retrofitted into existing plants with little risk.

The overall goal of this three-year project is to build and operate a 500 m2 prototype low-pressure counter-flow sweep membrane module. Development of this new type of very large area membrane contactor module will significantly increase the feasibility of using membrane technology to separate CO2 from coal-fired power plant fuel gas. Availability of this type of module also opens up the possibility of creating synergistic combinations of a membrane pre-concentration step and a second final concentration step such as absorption, adsorption and cryogenic separation. The feasibility of these combination processes will be evaluated during this project.

Carbon Capture Scientific LLC, along with CONSOL Energy Inc., Western Kentucky University, and Nexant Inc., will perform bench-scale development and testing of a novel gas pressurized stripping (GPS) process-based technology for carbon dioxide (CO2) capture from post-combustion flue gas. The GPS process removes CO2 through solvent-based absorption and stripping, applying two innovations to improve the thermal efficiency over conventional columns: the use of a high-pressure stripping gas in place of water vapor to increase operating pressure, and the addition of heat through multiple locations along the stripping column to eliminate temperature gradients. The project objectives are to conduct bench-scale testing of individual process units; optimize the GPS column with computer simulations for both new and retrofit applications; perform an experimental investigation of selected solvents; conduct bench-scale testing of a rotating packed bed at anticipated absorption conditions; and design, build, and operate a bench-scale GPS unit capable of achieving at least 90% CO2 capture from a nominal 500 standard liters per minute coal-derived flue gas slipstream at the National Carbon Capture Center. The project team will complete a techno-economic study and an environmental, health, and safety risk assessment for the GPS process.

The Ohio State University (OSU), along Gradient Technology, TriSep Corporation, and American Electric Power, will develop a cost-effective design and manufacturing process for novel membrane modules that efficiently capture carbon dioxide (CO2) from power plant flue gas. The innovative membrane design combines the selectivity and stability of inorganic microporous membranes and the cost and flexibility of polymer materials. The membranes consist of a thin selective inorganic layer embedded in a polymer structure that allows it to be manufactured in a continuous process. This design will result in hybrid membranes with exceptionally high CO2 permeance, high selectivity of CO2 over nitrogen, and the full operational stability needed for energy-efficient CO2 capture. The membranes will be incorporated in spiral-wound modules and implemented in a two-stage CO2 capture process with the potential to achieve greater than 90 percent CO2 capture of at least 95 percent pure CO2. Three prototype membrane modules will be fabricated and bench-scale testing will be conducted with simulated flue gas to validate the membrane performance. Technical and economic feasibility studies will be completed, as well as an environmental, health, and safety assessment.

Fuel Cell Energy, Inc. (FCE), in collaboration with Pacific Northwest National Laboratory, URS Corporation, and Western Research Institute, will further develop its patented Combined Electric Power and Carbon-Dioxide Separation (CEPACS) system for carbon dioxide (CO2) separation and compression from pulverized coal (PC) power plants. The CEPACS system is based on an electrochemical membrane (ECM) technology derived from FCE's internal reforming carbonate fuel cell product, Direct Fuel Cell®. The unique chemistry of carbonate fuel cells provides a method to remove CO2 from the flue gas of PC plants and simultaneously produce additional clean electric power at high efficiency using a supplementary fuel, such as coal-derived syngas, natural gas, or a renewable resource. Therefore, the CEPACS system increases the power generated by the existing fossil-fueled plant, unlike other CO2 capture technologies that reduce net electric power. The ECM module consists of ceramic-based layers filled with carbonate salts that separate CO2 from the flue gas with a selectivity of 100 percent over the nitrogen present. Operating at atmospheric pressure, the ECM module does not require flue gas compression, and because of fast electrode kinetics, does not require a high CO2 concentration, making it suitable for use at the concentrations normally found in PC plant flue gas. Additionally, the planar geometry of the membrane offers ease of scalability to large sizes suitable for deployment in PC plants. In this project, researchers will conduct small-scale component fabrication and testing, contaminant pretreatment evaluation, and bench-scale testing of an 11.7 square meter ECM separation unit with simulated flue gas. A techno-economic feasibility study and an environmental, health, and safety assessment will be completed at the 550 megawatt PC power plant level. Predecessor Project::DE-FC26-04NT42206 Successor Project::DE-FE0026580

Southern Company Services, Mitsubishi Heavy Industries America (MHIA), and URS Group have teamed to develop viable heat integration methods for the capture of carbon dioxide (CO2) produced from pulverized coal combustion plants, improving upon the current state-of-the-art for solvent-based capture processes. An advanced level of heat integration between the power plant and the CO2 capture facility will be investigated by incorporating a waste heat recovery technology into an existing amine-based CO2 capture process. The project will incorporate MHIA High Efficiency System (HES) heat recovery and integration technology into an existing 25 megawatt electrical (MWe) pilot plant demonstration of the Kansai Mitsubishi Carbon Dioxide Recovery (KM-CDR™) CO2 capture process at Southern Company Plant Barry. The HES heat integration technology will use waste heat streams to provide needed process stream heating, reducing the amount of low pressure (LP) steam extracted for the solvent regeneration system. The recovered heat will also be used to heat boiler feed water, further reducing the extraction steam demands on the LP turbine and increasing the LP steam available for power generation. The HES has been successfully demonstrated at several low-sulfur, coal-fired power plants outside of the United States, though not with CO2 capture. This project will examine the HES performance with high-sulfur flue gas, and as integrated with a CO2 recovery system. A preliminary techno-economic analysis has indicated that HES with advanced heat integration can reduce the total energy impact of a CO2 capture system by 26 percent, a significant step toward meeting the Department of Energy goal for the cost of electricity.

New Award with West Virginia University Research Corporation for a project titled "U.S.-China Carbon Capture and Storage Development Project at West Virginia University". The objective of this project is to undertake resource evaluation and planning for the execution of two pilot demonstrations carbon capture and storage projects and to describe and quantify the geologic, environmental and economic challenges to large-scale carbon capture and storage in China.

NexTech Materials is developing new manufacturing techniques for coating metals to lower the cost and improve the long-term durability of solid oxide fuel cells.

The goal of Exelus is to create a complete, sustainable, and cost-effective technology that converts algal oil-derived biodiesel into jet fuel. The proposed technology steps far beyond traditional biodiesel synthesis to convert a ready source of fuel, algal oil, into aviation fuel that meets or exceeds all current performance specifications. This project applies completely new chemistry with environmentally benign engineered catalysts that allows conversion of both triglycerides and free fatty acids found in algae oil into long-chain branched paraffins that are ideal jet fuel components.

Wireless Sensor Technologies is developing and demonstrating a high reliability waste heat-enabled power supply and wireless sensor system for power generation applications. The system consists of networked sensor nodes containing pressure and temperature sensors that may be used in the hot sections of turbine engines and mounted on rotating components enabling condition-based maintenance for a power generation plant.

Barber-Nichols proposes development of combined novel rapid manufacturing process "Electron Beam Melting" EBM, with a rapid material removal process "Electro Chemical Machining" ECM, to provide a low-cost, high-quality alternative to the traditionally expensive and time consuming casting processes for industrial gas turbine engines. The combined process developed under this SBIR will enable significantly shorter engine development cycle times as well as provide a faster, lower cost approach for the manufacture of complex cast parts across multiple industries.

FuelCell Energy, Inc. (FCE), in partnership with Modine Manufacturing Company and BASF Catalysts, is proposing the development of a novel catalytic heat exchanger which combines the functionality of the separate catalytic combustor and cathode air preheater into a multi-functional single unit. Applying this innovative technology to SOFC power systems has the potential significantly reduce BOP costs while also meeting the severe technical design requirements. In addition to the high operating temperature and temperature differentials, the heat exchanger must also be designed to withstand a corrosive environment on the source-side (H2O, O2), thermal cycling, and impart very low pressure drop on both the source and sink sides. Low cost is also a key criterion for design of the cathode air preheater. The proposed research and testing program is anticipated to address critical design challenges through multidisciplinary design optimization and lab-scale component testing.

This project will support the development and demonstration of a novel instrument with unprecedented sensitivity, accuracy and reliability for monitoring and control of combustion emissions and of power plants and industrial processes; for engine diagnostics and for automobile monitoring; and for measurements of atmospheric pollutants, trace gases and greenhouse gases.

This project will develop new technology for controlling mercury emissions and environmental releases associated with the operation of coal-fired electric power generation plants and the processing of byproducts. This control will be achieved through the use of chemical additives in the power plant's flue gas desulfurization (FGD) system. These additives will: (1) sequester mercury into the liquid phase; (2) prevent mercury re-emissions into the flue gas; (3) prevent precipitation and adsorption of mercury on primary FGD byproducts such as gypsum; and (4) precipitate mercury from the FGD blow down stream, as a stable solid byproduct that is segregated from other FGD solid byproducts.

Develop direct diode laser systems and processes for improved cladding of high temperature materials for ultrasupercritical boilers

Specifically, this project seeks to develop and validate a single-can reheat combustor for 50 MWth firing rate at 600-650 psia to increase exhaust from 450-600C (840-1100F) to 1760C (3200F) with a particular focus towards possible future integration of the reheat combustor within the overall Siemens-CES Oxy-Combustion Cycle System, where reheating high-steam content gas from HP turbine represents a key technical challenge.

Aspen Aerogels will develop a novel CO2 capture solid sorbent for coal fired power plants. The novel aerogel sorbent will 1) effectively remove the CO2 from post combustion flue gas, 2) will be regenerated at low temperature, and 3) will be suited for multiple-cycle use. The new developed technology will enable to retrofit the existing fleet of coal-fired power plants for carbon capture and minimize global warming caused by greenhouse gas emissions.

The overall objective of a multi-phase SBIR effort is to research, design, develop, test, evaluate, benchmark, and bring to production an intelligent valve positioning control solution that can provide much more robust and precise control for large-scale coal-fired power plants using CyboSoft's innovative yet industry proven Model-Free Adaptive control technology. Phase I work evaluated, simulated, and determined the feasibility of using Model-Free Adaptive control technology to develop an intelligent control solution for valve positioning control to meet stringent performance specifications and show that the solution can effectively deal with large variations in valve gain, time constant, delay time, and other bad valve behaviors. Phase II efforts will build upon these developments to experimentally show and optimize the software solution for valve control and lead to more precise control at the local/low level and improve performance of the system.

The objective of Phase I of this program is to evaluate the technical merit and feasibility of a Direct Coal power plant incorporating a Liquid Tin Anode Fuel Cell.

This research consists of a computational-experimental effort and will dovetail the thermodynamic and kinetic concepts of high temperature reactions involving metals and ceramics with the computational fluid dynamics and computational modeling to develop the plasma processing of high temperature scales for metals and ceramics.

The goal of the project is to develop a novel and competitive processing route for manufacturing MoSi2-based composites. Specifically, the project will investigate use of mechanically activated self-propagating high-temperature synthesis (MASHS) followed by compaction. Conventional self-propagating high-temperature synthesis, also called combustion synthesis, promises great advantages such as low energy consumption and low cost, but in case of MoSi2-based materials the reaction rates are not sufficiently high and the products have high porosity and low density. The mechanical activation will improve the reaction kinetics in the subsequent SHS process, while the final compaction will decrease the product porosity. As a result, the problems of SHS will be overcome and its great advantages will be used effectively.

The goal of this project is to identify through ab initio molecular dynamics atomic level modeling and computer simulation and then experimentally validate new oxide dispersion strengthened (ODS) steel alloy compositions that have improved high temperature mechanical and corrosion resistance properties for advanced fossil energy applications. To accomplish this goal the project team will (1) Build interface models of ODS alloy compositions. (2) Perform interface energy and molecular dynamics/Monte Carlo high performance computing (HPC) simulations on the ODS models to identify promising compositions for high temperature and high pressure applications. (3). Perform experiments on the high temperature oxidation and high temperature/high pressure dislocation creep properties of the most promising ODS systems from the simulations.

UTEP will study the particle dynamics of liquid-fueled high velocity oxy-fuel (LHVOF) process for a range of operating and process parameters and study the effects of these operating and process parameters on coating characteristics to determine the ability of the system to produce FeAl based coatings that meet the performance requirements of advanced fossil power generation systems.

NexTech Materials will demonstrate the applicability of their aluminization process to solid oxide fuel cell (SOFC) applications. Two commercially important systems will be investigated: (1) Compatibility of aluminide coating with SOFC stack components will be evaluated, including interactions with sealant materials and other cell components. A complete interconnect coating solution will be demonstrated by integrating the aluminide coating with the existing manganese cobalt oxide (MCO) active layer coating. The performance of these dual MCO/aluminide coated interconnects will be validated through three-cell stack tests. (2) The high-temperature corrosion protection and chromium volatilization mitigation of aluminide coated balance-of-plant (BOP) components will also be evaluated. The commercial potential of the aluminization process for providing protective aluminide coatings for both the non-active seal area of metallic interconnects and BOP components will be quantified based on an analysis of cost and performance. This work leverages NexTech’s process technology for applying conductive oxide protective coatings to ferritic steels and has already been translated from the laboratory to pilot-scale manufacturing.

This project will develop and build a system for long term monitoring of CO2 reservoirs to confirm the integrity of the seal. The purpose of storing CO2 is to mitigate its effect on the atmosphere and climate.

Gasification technologies convert coal and biomass into synthesis gas feed streams that can be used for power generation cycles or converted into value-added chemicals and transportation fuels. However, coal-derived synthesis gas contains many trace contaminants that should be removed prior to downstream processes. TDA Research, Inc. (TDA) is developing a low-cost, high capacity sorbent that can remove ammonia (NH3) and hydrogen cyanide (HCN) and trace metal contaminants (such as mercury, arsenic, and selenium) from coal- and coal/biomass-derived synthesis gas in a single process step. TDA will determine the effect of operating parameters, conduct multiple-cycle experiments, and test sorbent life. Unlike the commercially available gas clean-up technologies, the TDA multi-contaminant control system operates above the dew point of the synthesis gas (500 degrees Fahrenheit). With this technology, the synthesis gas would not have to be cooled in order to remove the contaminants, thus improving the thermal efficiency of the process. This technology has the potential to improve the energy efficiency and process economics for producing electric power from coal gasification.

With careful design of micro-alloying composition, heat treatments as well as microstructure, this project will develop the next generation of austenitic stainless steels that will be able to operate at high temperatures above 850 degrees Celsius for future power systems.

High-entropy alloys (HEAs) have emerged as suitable materials for high-temperature applications in excess of 800 degrees Celsius (ºC). HEAs have revolutionized alloy design by using several principal elements as opposed to traditional alloys which consist of one or two principal elements with small additions of alloying elements to achieve desired properties. For this project, the University of Tennessee will perform fundamental studies on the aluminum-chromium-copper-iron-manganese-nickel HEA system for use in boilers and steam and gas turbines at temperatures above 760ºC and stress of 35 megapascals. They will also develop an integrated approach coupling thermodynamic calculations and focused experiments to identify HEAs that outperform conventional alloys.

This project will fabricated novel double-layer functionally graded TBCs will be using High Velocity Oxy-Fuel thermal spray (HVOF) and/or Air Plasma Spraying technology. The TBC materials will be characterized, their corrosion resistances at elevated temperature and corrosive environments will be evaluated, and their performance under corrosive environments at high temperatures will be measured. Additionally, parameters that affect residual stresses in TBC laminates, such as composition and thickness of layers will be identified. Laminated materials with the desired bulk residual stresses will be designed and their failure mechanisms and mechanical performances will be studied. Finally, a computational model to predict residual stress in the TBCs will be developed.

The overall objective of this proposed research is to elucidate the feasibility of two-layer air plasma-sprayed (APS) thermal barrier coatings (TBCs) for next generation gas-turbine engines fueled by coal-derived syngas. First, optimized two-layer 48YSZ/7YSZ TBCs on bond-coated superalloy substrates will be fabricated and characterized. Then the mechanical and thermal properties of the new TBCs will be measured. After, the high-temperature interactions between lignite coal fly ash and the new TBCs at high temperatures (isothermal conditions) will be investigated. This will be followed by an investigation into the thermal cycling behavior of new TBCs under thermal gradient conditions with spray of lignite coal fly ash and water. The thermo-chemomechanical failure and durability of the new TBCs tested under those conditions will then be modeled. Finally, the technology pertaining to the new TBCs with optimized compositions and microstructures will be transferred to original equipment manufacturers for further development and possible utilization in next generation gas-turbine engines fueled by coal-derived syngas.

This project further develops and demonstrates the sensor technology developed under a previous project, "Real Time Flame Monitoring of Gasifier Burner and Injectors" DE-FC26-02NT41585. GTI developed a reliable, practical, and cost-effective means of monitoring coal gasifier feed injector flame characteristics using a modified version of an optical flame sensor. The present work begins with modification of the sensor software to enable real-time temperature data acquisition, data processing, and provision of the collected gasifier temperature information to the gasifier operators. A new purging system will be developed to eliminate or significantly reduce the deposition of fine black powder on the optical probe window during sensor operation with the goal of increasing the period of continuous deposit-free operation to six months. The modified gasifier sensor will be installed at the Wabash River commercial gasifier in Vigo County Indiana and tested over a six-month period to evaluate the sensor’s accuracy and durability. The project team will prepare a commercialization plan describing the product, the market, and the business activities required to make this new technology available for industrial use.

This research project addresses some of the materials issues for the successful implementation of the supercritical and ultra supercritical Rankine cycles. The goal of the effort is to develop new coatings to improve corrosion resistance of boiler materials, fireside corrosion protection of tubes and turbine blade materials. The new coating will be prepared by High Velocity Oxygen Fuel Spraying (HVOF) spray coating of TiC and TiB2 nanoparticles synthesized by a patented process. The specific objectives of the proposed project are a) synthesis of nanoparticles of TiC by a patented process, b) extension of the process to synthesize nanosized TiB2 powder, c) optimization of ( HVOF spray coating of the TiC and TiB2 on select ferritic, austentic and nickel alloy samples generally used for waterwall tubing, high temperature boiler sections, turbine blades and ultra supercritical (USC) tubing applications, d) laboratory evaluation of the corrosion resistance of the coatings employing simulated flue gas and simulated ash, e) selection of optimum alloy protection system in different temperature/chemical regimes and f) field evaluation of fabricated probes of select coating in actual boiler/turbine environment.

The objectives of the proposed research are two-fold: (a) develop a methodology for microstructural optimization of alloys - genetic algorithm approach for alloy microstructural optimization using theoretical models based on fundamental micro-mechanisms, and (b) develop a new computationally designed Ni-Cr alloy for coal-fired power plant applications. The broader outcome of these objectives will be the creation of an integrated approach for 'materials by microstructural design.'

The project objective is to develop models of both the precipitation kinetics and deformation behavior of aluminum-alloyed, Laves phase-strengthened, austenitic steels. Specific objectives for the first year of the project include thermomechanical processing of fifteen specimens, microstructural analysis of the matrix and precipitates, and mechanical testing to determine room-temperature yield strengths and elongations in five specimens. Second-year objectives are thermo-mechanical processing of twenty specimens; microstructural analysis of particle size, spacing, precipitate chemistry, and tomography to select samples of interest in each state; mechanical testing to measure creep rates of microstructures, deformation analysis at various temperatures, and analysis of fracture behavior; and transmission electron microscopy (TEM) to analyze dislocation/precipitate interactions. Year three objectives include completing TEM in-situ annealing experiments, developing quantitative models to describe precipitation processes, and determining the relationship of microstructures to mechanical properties under various conditions. Scientific insight into the effects of prior deformation on the precipitation processes and resultant mechanical properties of these advanced materials will provide a basis for the specification, design, fabrication, operation, and maintenance of advanced power generation plants.

The University of Toledo will devise material processing techniques for the development and evaluation of two new groups of oxygen carrier materials based on a crystal structure and will systematically investigate their carrier formulations. These new oxygen carriers would be used in chemical looping combustion systems, and would be more thermally and chemically stable than materials currently being considered for this application.

The objective of this project is to develop, test, and apply an advanced joint data inversion tool to enhance the predictive capability of models regarding the fate of CO2 plumes, and to improve storage performance through better understanding storage systems. The joint inversion tool can be used for decision-making for optimal control of CO2 injection and storage by linking forward simulation, dynamic monitoring and inversion, uncertainty quantification, and risk assessment under a consistent framework.

The University of Maryland (UMD) project is a multi-faceted fundamental investigation of the effects of contaminants on cathode degradation mechanisms in order to establish cathode composition/structures and operational conditions to enhance cathode durability. The results will be used to develop hypotheses that explain the microstructural and compositional cathode performance degradation mechanisms and mitigation strategies. Phenomenological models will be developed concurrently to describe the role of architectural and operational variables on cathode performance and stability. These will result in the formation of design criteria that will be validated experimentally in terms of electrochemical performance stability in the targeted contaminant containing air in long-term tests.

This West Virginia University project will focus on advancing the fundamental understanding of how solid oxide fuel cell cathodes operate such that their performance can be improved. The project will center around the role of material interfaces in determining electrochemical performance. Advanced physical characterization tools will be employed in support of a coordinated approach consisting of reaction modeling and a focus on a novel cathode material combination of Lanthanum Nickelate + Lanthanum Strontium Iron Cobalt Oxide. The results will be interpreted to determine the operation mechanisms and identify new material architectures thereby enabling improved fuel cell performance.

The study will research new steels capable of operating at 760 degrees Celsius in the aggressive environments of advanced ultra-supercritical (AUSC) boilers and steam turbines. New compositions and new strengthening mechanisms or microstructures will be identified, using high-throughput diffusion multiples—an assembly of different metals which are subjected to high temperature, creating intermetallic compounds—and computational thermodynamics. Steel compositions with high iron and chromium concentrations will be the focus of this exploration because high iron concentration—instead of expensive nickel-based super alloys—is important for cost reduction and high chromium concentration is essential for oxidation and hot-corrosion resistance.

Mikro Systems Inc (Mikro) intends to extend the use of their Tomo Lithographic Molding (TOMO) manufacturing platform within the investment casting process through the development of engineered ceramic filters for metal casting. Current state casting filters are not sophisticated from a design perspective and no specific filters have been engineered for single crystal (SX) casting. This project will focus on developing ceramic filters that will optimize filtration performance while enabling directional flow of molten alloy during the SX casting process. These performance advantages will be enabled through the geometric design of the filter. Another anticipated benefit is the ability to design part-specific filtration schemes for advanced airfoil castings.

Stanford University will identify correlations between performance and the microscopic surface properties of oxygen reduction reaction (ORR) active sites in state-of-the-art solid oxide fuel cell (SOFC) cathodes, quantified using novel in situ spectroscopy, scattering, and microscopy techniques, while the electrochemical reactions take place under SOFC operating conditions. In particular, the characteristics of active sites that display high electrochemical activity will be identified. This fundamental knowledge will be used to rationally engineer electrode surfaces in both idealized and, later, porous lanthanum strontium cobalt ferrite (LSCF) and similar cathodes. Finally, the effort will optimize and validate the electrode modification strategies using button-cell SOFCs. This project relies on using three new approaches to measure cathode surface characteristics in situ: (1) X-ray spectroscopy, (2) X-ray diffraction, and (3) transmission electron microscopy (TEM). The team will utilize two U.S. Department of Energy (DOE) Office of Science user facilities: the Advanced Light Source (ALS) facility at Lawrence Berkeley National Laboratory and the Stanford Synchrotron Radiation Light source (SSRL) facility (a directorate of SLAC National Accelerator Laboratory operated by Stanford University) to carry out in situ X-ray experiments. A Sandia Laboratories field work proposal, FWP-12-015990; supports this work.

This project is focused on studying performance of CO2 storage at a Rock Springs Uplift (RSU) potential storage site in southwestern Wyoming using a multidisciplinary approach that integrates observational, experimental, and theoretical data with numerical simulations and determinations of seismic attributes. The objectives include: (1) Reduce uncertainty in estimates of CO2 storage capacity at the RSU; (2) Evaluate and ensure CO2 storage permanence at the RSU site by focusing on the sealing characteristics and 3-D interval heterogeneity of the confining layers; (3) Improve the efficiency of potential storage operations by designing an optimal coupled CO2 injection/brine production strategy that ensures effective pressure management; and (4) Improve the efficiency of brine production in the RSU relative to mineral scaling.

This University of Wisconsin project will focus on advancing the fundamental understanding of how solid oxide fuel cell cathodes operate such that their performance can be improved. This project will center around the role of material interfaces in determining electrochemical performance. Advanced physical characterization tools will be employed in support of a coordinated approach consisting of ab initio modeling and a unique electrochemical characterization technique called Non-Linear Electrochemical Impedance Spectroscopy. The results will be interpreted to determine the operation mechanisms and identify new material architectures thereby enabling improved fuel cell performance.

The project objective is to develop a novel application of a pH-triggered polymer gelantto seal leakage pathways associated with existing wellbores which are difficult to treat with currently available technologies. The effort is testing gelant formulations under a variety of conditions relevant to field applications and determining which is optimal for stopping the flow of brine, brine containing dissolved CO2, or bulk phase CO2. The modeling objective is to develop simple models of the key processes involved in this application, including the transport and reaction of a low-pH fluid (the gelant) through fractures in strongly alkaline materials (cement and earth formations), the rheology of the gelant and gel, and the coupled flow/transport/reaction before, during and after gelant placement in the leaking formation/leakage pathway/recipient formation system. The researchers are validating the components of the models against the laboratory experiments, and apply the coupled model at the wellbore scale to analyze possible leakage remediation strategies and to design the placement of gelant to achieve those strategies.

The University of Connecticut (UConn) team will perform an evaluation and analysis—using experimentation and computational simulation—of degradation phenomena in lanthanum manganite- and cobaltite-based cathode electrodes when exposed to air atmosphere conditions during solid oxide fuel cell (SOFC) operation. The project will examine the role of dopants, electric polarization, gas phase contaminants, oxygen stoichiometry (proportions), and A:B ratio on the long-term bulk and interfacial stability of lanthanum manganite and cobaltite cathodes. Cathode materials will be characterized to develop both initiation and propagation processes responsible for chemical and morphological changes. The role of electrode poisoning in the presence of chromium vapor will be examined using existing test facilities capable of generating a wide range of vapor pressures in humidified air.

The project is seeking to optimize CO2 storage capacity and containment in critical geologic formations by establishing field methodologies focused on (1) the quantification and enhancement of CO2 storage capacity in saline formations and (2) the optimization and quantification of CO2 storage in hydrocarbon reservoirs in association with CO2 enhanced oil recovery (EOR). The goal of the saline formation activities is to refine, as necessary, the equations to develop CO2 storage capacity/resource estimates and the storage coefficients used to calculate those estimates based on regional-scale models.

Princeton researchers are developing a suite of models of varying complexity, testing them against each other using actual CO2 injection cases, and showing how some can be used to help resolve important practical design issues associated with optimal placement of wells for CO2 injection, brine extraction, and system monitoring. This exercise is demonstrating the degree to which models of different complexity can be used to address design and optimization issues associated with placement and scheduling of injection, extraction, and observation wells. Ultimately, study findings will help determine when simplified models are appropriate for CO2 storage modeling.

The overall goal of this Boston University project is to deepen the fundamental knowledge and understanding of solid oxide fuel cell interfaces and to employ such understanding to greatly improve electrochemical performance while meeting SECA cost, stability, and lifetime targets at the cell level. Boston University plans to employ newer cathode and electro catalyst materials and a variety of experimental and computational tools to achieve this goal. The specific objectives include: (i) Separating and identifying the influence of oxygen surface adsorption, transport pathways, electron transfer reaction, and incorporation into the electrolyte in the overall oxygen reduction reaction; (ii) Identifying the role and time evolution of the cathode surface and buried layer interface structure, surface electronic properties, surface composition, and the oxidation state of the transition metal ions during the oxygen reduction process; (iii) Using new materials combinations and architectures based on the knowledge gained from (i) and (ii), demonstrate a 50 percent improvement in performance in maximum power densities of cells compared to baseline cells employing state-of-the art materials and cell stability that shows 0.1 percent or less per 1000 hours degradation in cell performance.

The goal of this research was to identify means of improving CO2 storage efficiency and plume distribution for varying degrees of heterogeneity in geologic reservoirs of different depositional environments identified by DOE as promising storage formations. The approach to achieving this goal included: 1) completing a preliminary screening of Illinois Basin (ILB) geologic formations that represent a broad and diverse portfolio of promising geologic depositional environments for CO2 storage; 2) developing geologic models of ILB geologic formations that are suitable to represent the desired depositional environments and formation classes; 3) using the models to determine baseline estimates of storage efficiency for each of the formation classes; and 4) determining the potential incremental improvements in storage efficiency that could be realized for each of the formation classes by applying various field methods or operational techniques.

The objective of this project is to develop and validate—based on simplified physics, statistical learning, and/or mathematical approximations—a portfolio of simplified modeling approaches for geologic CO2 storage in deep saline formations for predicting: (1) Injection well and formation pressure buildup; (2) Lateral and vertical CO2 plume migration; and (3) Brine displacement to overlying formations and to the edges of the plume pressure front within the storage formation. Such computationally-efficient alternatives to conventional numerical simulators can be valuable assets during preliminary CO2 injection project screening, serve as a key element of probabilistic system assessment modeling tools, and assist regulators in quickly evaluating geologic storage projects. Additionally, these approaches will improve existing simplified models in their applicability, performance and cost.

The Georgia Institute of Technology (Georgia Tech) will use specially-designed electrodes and cells, such as electrodes of thin films and patterned electrodes, to study the electrochemical response of lanthanum strontium cobalt ferrite (LSCF) cathodes under realistic operating conditions (ROC), to probe and map contaminants on the LSCF, and to characterize the correlation between electrochemical performance and microstructure/morphology of LSCF cathodes as well as their evolution over time. A range of characterization tools will be used to study the chemical and structural changes during fuel cell operation. Electrochemical techniques, such as impedance and DC polarization, will be intensively applied to characterize the cathode performance, which will be correlated with the structural and compositional evolution of the LSCF cathode under ROC. Proper characterization, modeling techniques, and prediction tools will be used to help in formulating an effective strategy to mitigate the stability issues and predict new catalyst materials that can enhance the stability of LSCF. Finally, the performance and stability of the modified LSCF cathode will be validated in commercially available cells under ROC.

The project aims to investigate fundamental model complexity in representing coupled physical and chemical processes that accompany carbon storage operations in hierarchical subsurface geologic media. Specifically, the research is focused on developing a simulation and upscaling methodology that is generally applicable to sedimentary environments that are characterized with multiple scales of permeability, heterogeneity, and diverse mineralogies. This will include investigation of the effect of increasing reservoir permeability variance and depth on the uncertainty outcomes including optimal heterogeneity resolution(s) and investigation of the effect of mineral reactions occurring in the subsurface in geologic storage systems, including mineral volume fractions, reactive rate constants, reactive surface areas, and the impact of different geochemical databases.

The objective of this project is to assess depositional, structural, and diagenetic characteristics of caprock/reservoir interfaces across the midwestern region, and how insight gained from observation linked to coupled modeling can contribute to best modeling practices. The project will complete a systematic assessment of wellbore integrity using regulatory and industry information. Specifically, this project is developing a short-list of oil/gas, gas storage, or injection wells in the Appalachian and Michigan Basins for a detailed assessment of well history and to collect sustained casing pressure and mechanical integrity test data. The project will determine the distribution of wellbores in a study area through collection and analysis of well records. Technical items such as cement degradation, cracks and microannulus, acid-gas zones, channeling, casing corrosion, wellhead leaks, and sustained annulus pressures are being evaluated with historical well records, field monitoring of selected gas storage wells, and review of regulatory information. The data review will be linked to analysis of well casing annulus pressure data as they relate to well condition. Project results will identify and develop methodologies that can indicate future wellbore integrity risks from available public domain data with high confidence.

This project will determine the feasibility of a Coal-Biomass to Liquids (CBTL) facility in southern West Virginia. The study will include economic, technical, and financial feasibility along with a market analysis for CBTL fuel. For the analysis, three production scenarios will be used to determine the best technology, while multi-objective programming will be used to identify the best strategies for feedstock management, facility operations, and locating sites.

The University of Kentucky Center for Applied Energy Research (CAER) is developing a heat-integrated coal-based combined cycle for power generation using a pressurized chemical looping combustor (PCLC). The PCLC system may achieve an overall plant thermal efficiency of approximately 48 percent [lower heating value (LHV)] by passing the high-temperature flue gas through a gas turbine for electricity generation and a heat recovery steam generator (HRSG) for supercritical steam production used to drive a conventional steam cycle. The PCLC system contains an oxidizing reactor, in which oxygen from air is selectively fixed into an oxygen-carrier structure, and a reducer reactor in which coal is burned by the oxygen carrier. The PCLC will generate two gas streams: (1) a high-temperature, high-pressure, alkali-free, clean gas stream from the oxidizer used to drive a gas turbine followed by a HRSG, and (2) a small-volume CO2-enriched stream from the reducer for sequestration. Advantages of the PCLC system include lower power requirements for compression of the enriched CO2 stream, reduced reactor size due to elevated operation pressure, and significant reduction to cost of electricity (COE) of a commercialized CLC power plant by using a relatively high-performance and cost-effective iron-based oxygen carrier. The PCLC system holds potential to meet DOE target of limiting the energy penalty with no more than a 35 percent increase in the COE, while capturing at least 90 percent of the CO2 released during the combustion of fossil fuels. A design basis and final design package will be developed in Phase I. The major equipment will be sized using data obtained from previous thermogravimetric analyses and bench- and pilot-scale apparatuses operated at CAER and Southeast University (SEU), respectively. The data will be used to determine suitable reaction kinetics, oxygen carrier make-up rate, carbon slip ratio between air and fuel reactor, as well as temperature and pressure profiles along the reactors. A rate-based Aspen Plus® process model will be built for the heat-integrated combined cycle to provide the necessary stream table for technical analysis. A detailed process design basis and engineering flow chart with appropriately sized equipment will be provided for an economic analysis of a commercial-scale PCLC system.

Alstom Power, through prior U.S. DOE funding, has been developing a limestone-based chemical looping combustion technology. The selected project will continue this work by enabling the full analysis of the process through an engineering system and economic study along with the development of a screening tool for process improvements. Additional analyses include an evaluation of pressurizing the limestone chemical looping combustion process.

Gas Technology Institute (GTI) is developing a pressurized, oxy-coal combustor. CO2 capture is simplified when firing with oxygen instead of air. Traditional combustors cannot operate with the high oxy-coal adiabatic flame temperatures and are modified with high flue gas recirculation (FGR) or water injection that significantly reduces plant efficiency. The proposed molten bed oxy-coal combustor is a disruptive technology that offers higher efficiency than existing oxy-coal combustors by greatly reducing FGR and by operating at elevated pressure. The unique combustion and heat transfer design employs a smaller less expensive combustor and reduced gas phase heat exchanger surface area. Decreased FGR results in reduced capital and maintenance costs. Anticipated benefits include a calculated plant efficiency increase of 4%, large reduction in FGR duct and equipment sizes, lower exhaust gas volume and gas handling and cleaning equipment, reduction of boiler sizes by more than 50%, decreased convective path heat exchanger surface area and maintenance, near elimination of fine ash carryover into the exhaust gas, and recovery of ash/slag as aggregate instead of as micron sized particles.

GTI will be conducting engineering design and economic analysis based on the pressurized, oxy-coal molten bed combustor following the NETL protocol with comparisons to the specified baseline supercritical steam power plant burning Illinois #6 bituminous coal. Goals for this project include coal injector testing, engineering designs, mass and energy balance calculations around this advanced combustor, energy and exergy analysis, and corrosion assessment.

Researchers are developing a coupled flow and geomechanical model capable of simulating the poromechanics of faults to assess the potential for fault slip and fault activation upon CO2 injection. The specific objectives of this project are: (1) develop efficient mathematical and computational models of the coupling between CO2 injection and fault mechanical deformation; (2) develop high-resolution computational methods of CO2 migration during injection and post-injection for better predictions of capillary and solubility trapping; and (3) apply the models of fault poromechanics and CO2 migration and trapping to synthetic reservoirs.

This project will develop coaxial cable based sensor devices in conjunction with subsurface modeling to detect temperature, pressure, and strain for subsurface installations. Developments will be a novel ceramic coaxial cable sensor technology and associated instrumentation for down-hole harsh environment sensing applications and also the demonstration of the sensors applicability towards long-term, reliable monitoring of carbon dioxide injection and storage in deep geologic formations.

The proposed work targets the development of a robust pH sensor for in situ monitoring of subsurface waters. The pH of the water will reflect dissolved CO2 and can thus infer CO2 plume migration. The downhole pH/CO2 sensor will be developed to resist high pressures, high temperatures, and high salinity. Materials development work includes the use of a metal-oxide pH electrode with good stability and the understanding of different factor's effects on the performance of the electrode, after which sensor performance under high pressures, temperatures, and salinity conditions will be evaluated. Additional performance evaluations of the sensor will be carried out using CO2/brine core flooding tests, and a data acquisition system will be developed to enable pH and CO2 presence to be determined in situ.

The project objective is to explore the optimization of commercial CO2 injection and storage within the vertical geologic continuum from depth to surface by employing enhanced reservoir simulation methods to simulate plume(s) migration within the many possible storage layers comprising the massive clastic wedge that spans the Gulf Coast. Further, new storage efficiency factors are being generated that take into account regional injection and its impact on neighboring formations. The effort is creating new simplified screening models and developing a Best Practices Manual.

This project will evaluate a novel process for pressurized oxy-combustion in a fluidized bed reactor. The pressurized combustion in oxygen and the recycle of carbon dioxide gas eliminates the presence of nitrogen and other constituents of air, minimizing the generation of pollutants and enabling the economic capture of CO2 gas.

The project goal is to develop a 550 MW commercial-scale economic case study of Babcock and Wilcox (B&W) and The Ohio State University coal direct chemical looping (CDCL) process for CO2 capture and separation that can be used for retrofit, repowering, and/or Greenfield installations. Project objectives are to validate the CDCL process application for power generation through engineering system and economic analysis and an experimental, bench scale system suitable for addressing the identified technology gaps.

The overarching goal of this project is to advance the design, construction and operations of a coal/biomass-to-liquids (CBTL) facility at the University of Kentucky (UK) Center for Applied Energy Research (CAER) at 1 barrel per day (bbl/day) liquid fuels capacity.

Altex Technologies Corporation is fabricating and testing a lab scale liquid fuel production system using coal containing different percentages of biomass such as corn stover and switchgrass at a rate of two liters per day.

Geomechanics Technologies developed and demonstrated improved caprock integrity geomechanical simulation and risk assessment techniques to enhance performance of geologic storage systems and to assess and control geomechanics-related system failures (induced fracturing, faulting, bedding plane slip, or permeation through natural fractures and faults) at geologic carbon storage sites. This work provided a more expansive and detailed review and analysis of historical caprock integrity problems and incidents encountered by the gas storage and oil & gas injection industries. Data generated from the study can be used by other researchers to inform, compare, and validate alternative techniques for caprock integrity analysis and simulation. Additionally, the project developed and described an improved combined transport modeling and geomechanical simulation approach to predict and assess caprock integrity, with documented application to a wide range of geologic settings and operating conditions, including actual case histories.

This GTI (formerly Aerojet Rocketdyne) project will evaluate a novel process for pressurized oxy-combustion in a fluidized bed reactor. The pressurized combustion in oxygen and the recycle of carbon dioxide gas eliminates the presence of nitrogen and other constituents of air, minimizing the generation of pollutants and enabling the economic capture of CO2 gas.

Unity Power Alliance, in collaboration with their partners, will examine a novel pressurized oxy-combustion technology with potential for increasing process efficiency and reducing emissions and costs associated with CO2 capture and compression. This project will advance the state of the art in oxy-combustion technology by laying the groundwork for development of a pilot-scale oxy-combustion facility operating at very high pressure (up to 70 bar) with a heat recovery steam generator (HRSG) inlet temperature of 700 °C (current technology is at 605 °C) using a flameless combustion reactor. The system is expected to achieve an approximately 10 percent efficiency improvement over oxy-combustion at atmospheric pressure, reduce costs associated with CO2 compression, and avoid the need for costly and energy-intensive flue gas treatment.

The use of high pressure is expected to reduce the cost of electricity (COE) by improving generation efficiency through higher heat transfer rates, recycling of high temperature condensate, and by reducing capital and operating expenses associated with pressurizing the emitted CO2. In addition to the efficiency benefits, the capture of CO2 at higher pressure would enable nearly 100 percent CO2 capture and would cause the power cycle to generate more water than it consumes (the system would be "net water positive"). Condensate could be recycled for use in preparation of the coal-slurry feedstock, significantly reducing the water demands of the system.

In contrast to a conventional coal combustion furnace, flameless combustion approximates the conditions of an isothermal chemical reactor in which temperatures remain uniform and constant throughout the reaction process. This highly-efficient, carefully controlled reaction promotes complete combustion of coal at high temperatures with negligible generation of airborne particulates or hazardous pollutants. The majority of the pollutants that are normally released in flue gas are instead permanently entrained in a vitrified or glass-like slag. As a result, the use of a flameless reactor mitigates the need for costly and energy intensive flue gas treatment.

In Phase I, the project will encompass two independent research efforts: (1) computer modeling and optimization of pressurized oxy-combustion with a flameless reactor, and (2) design, construction, and testing of a 100 kilowatt (kW) bench-scale flameless reactor.

Wells used to inject CO2 and monitor carbon storage sites are completed with cement and steel piping that is designed to seal the wellbore and eliminate pathways for the CO2 to migrate out of the storage formation. These seals can be compromised if voids are present or the steel or cement degrades and cracks, necessitating methods to repair leakage pathways that can potentially facilitate migration of CO2. Researchers at the University of New Mexico (UNM) are examining ways to repair leakage pathways by modifying polymer cements with various nanomaterials to produce polymer-cement nanocomposites that have superior repair characteristics compared to conventional materials. The first phase of this research effort involves modifying polymercement slurries with various nanomaterials to increase their longterm performance in preventing CO2 leakage through the wellbore. Bond strength and fracture toughness testing will be conducted on the repair material bonded to the steel and cement. The slurries will be evaluated at the macroscale to determine their rheological properties, bond strength, fracture toughness, permeability, and durability against CO2 and brine water containing CO2 (Figure 1). Microstructural investigations of these nanocomposites will be conducted using nuclear magnetic resonance, X-ray diffraction, thermogravimetric analysis, scanning electron microscopy, and nanoscratch tests. The second phase involves testing the ability of select nanocomposite materials developed in the first phase to repair simulated flawed seal systems (Figure 2). Seal systems, composed of a casing (well pipe) set into a sheath of conventional well cement, will be created and various flaws (voids and fractures) will be incorporated into the cement and the cement-casing interface (corroded casing and artificially de-bonded interfacial regions). The samples will be placed in a pressure cell that mimics the pressures and temperatures found at CO2 storage depths and repair effectiveness will be measured. Post-test samples also will be examined for repair effectiveness and bond testing. The outcome will be an evaluation of the ability of the nanocomposite materials to repair flaws within the wellbore. The ability of the repair material to withstand supercritical CO2 will also be tested using a specialized system capable of delivering mixtures of CO2 and water at high pressures and specified flow rates

The goal of this project is to develop a biomineralization technology for sealing preferential flow pathways in the vicinity of injection wells. This was accomplished by characterizing an Alabama well test site, designing a protocol for and performing a field test, and evaluating the test results. The concept is based on the presence of the enzyme urease in some bacteria (i.e. Sporosarcina pasteurii) which hydrolyzes urea to form ammonium and increases pH. Urea is quite fluid and, when injected into a well, can penetrate deeply into small-aperture fractures in and around the wellbore. As a result of the bacterial activity, bicarbonate HCO (3-) is subsequently produced which in the presence of Ca( 2) precipitates calcium carbonate (Calcite), thereby sealing the fractures into which the urea has penetrated.

This Washington University project will develop and test a staged, pressurized oxy-combustion process and evaluate the economics of the system. The process incorporates fuel-staged combustion mode for power plants designed for carbon management. The approach permits control of temperature and heat flux associated with oxy-combustion. The potential benefits of the process are higher efficiency and lower capital and operating costs. Reduced gas volumes, oxygen and auxiliary power demands, and increased CO2 purity in the flue gas are additional anticipated benefits.

The overall goal of the project is to develop a validated carbon dioxide (CO2) subsurface model that combines the CO2 reactive transport and reservoir mechanics (pore structure changes due to dissolution and precipitation, and fracturing) with the intention of performing more physics-based simulations and predictions of coupled thermal-hydro-mechanical-reaction (THMC) behaviors due to CO2 injection. Additionally, the project will help in determining the mineralogical and chemical changes in the fluid and rock, and how these interactions affect porosity and permeability in different rocks. The project will also assess the role of reservoir mineralogy and petrography in controlling geochemical processes during CO2 injection.

GE Global Research will develop and demonstrate the technology for implementing multiple sensors on a fiber optic cable for remote monitoring of pressure and temperature in the harsh environment of deep underground CO2 sequestration wells.

Fischer-Tropsch (FT) process converts a mixture of carbon monoxide and hydrogen, called syngas, into liquid hydrocarbons. It is a leading technology for converting syngas derived from gasification of coal and coal-biomass mixtures to hydrocarbons in coal to liquids (CTL) and coal-biomass to liquids (CBTL) processes. However, conventional FTS catalysts produce undesirable waxes (C21+) that need to be upgraded to liquids (C5-C20) by hydrotreating. This adds significantly to the cost of FTS. The objectives of this Southern Research Institute project are (i) to demonstrate potential for CBTL cost reduction by maximizing the production of C5-C20 hydrocarbon liquids using a selective FTS catalyst and (ii) to evaluate the impacts of the addition of biomass to coal on product characteristics, carbon foot print, and economics. A novel bench-scale reactor system will be designed built and tested for economical and environmentally-sustainable conversion of coal-biomass feedstocks to gasoline- and diesel-range hydrocarbon liquids using the Fischer-Tropsch (FT) process chemistry. Selective FT conversion of coal- and coal-biomass derived syngas to C5-C20 hydrocarbon liquids will be carried out using a syngas slip-stream from the pilot-scale gasifier at the National Carbon Capture Center (NCCC). A novel FT catalyst being proposed removes the standard product upgrading and refining steps, allowing the CBTL process to become competitive with petroleum-based processes. Development and commercialization of a cost-effective gasification/FTS-based CBTL process to produce renewable gasoline is another step toward increasing the Nation's fuel supply diversity and energy security through the use of our abundant coal resources while at the same time protecting the environment.

The overall objective of this project is to design, build and deploy in the field an intrinsic fiber optic sensor system for subsurface CO2 plume migration monitoring and above-zone leak detection. Intelligent Optical Systems will develop field-deployable intrinsic optic sensors with wireless communication capability, conduct sensor evaluation and demonstration in simulated subsurface conditions, and demonstrate subsurface sensor deployment and operation. Intelligent Optical Systems plans to deploy and demonstrate the sensor system in a 5,200 ft. deep well and demonstrate the feasibility of using the system to detect actual injection of CO2 at hydrostatic pressures up to 2,000 psi. It is anticipated that the system will be mature enough at the end of the project to be incorporated in monitoring wells in the injection projects planned for Phase III of the DOE Carbon Sequestration Program.

This project will develop novel polymer membranes that utilize a mechanism known as facilitated transport, which can dramatically increase CO2 throughput and separation efficiency, providing cost and energy efficiencies needed to meet DOE goals. Novel polymer membranes that enable facilitated transport of CO2 will be taken from the laboratory bench-scale in preparation of testing on actual flue gas at a coal fired power plant

Researchers at University of Louisiana at Lafayette (ULL), and their partners from Missouri University of Science and Technology and Schlumberger Carbon Services, will use novel statistical-neural genetic algorithm methods to study the leakage risks for wells exposed to CO2. At a typical CO2 injection site, the CO2 plume could reach abandoned and active wells. There is an increased risk of CO2 leakage through these wells, particularly if the well construction quality is not well known. In many cases, construction information for older wells is limited or does not exist. The methodology and output of this study may be used to evaluate the leakage risks from existing wells at current and future CO2 storage sites, as well as older wells where all of the well construction data is not available by comparing similar well attributes and risks between similar types of wells. This study will first develop a comprehensive database of the wells in the Texas Gulf Coast area using electronic records that exist in the Railroad Commission of Texas, in addition to hard copy and microfilm data of older wells that exist in other government agency and private files. The database will be fed into a novel hybrid model of a neural-genetic algorithm, being developed as part of this project, to perform risk analysis across the database, and identify wells that should be subjected to remedial action. Statistical analyses will be performed by the model on general well attributes such as classification, well type, well construction details and materials, location, geology, geomechanical properties, wireline log data, mechanical integrity test data, plugging and abandonment reports, CO2 exposure duration, and reported well integrity problems of the wells. Multivariate statistical techniques, such as factor, regression and cluster, shall be used to analyze the database. In addition, the model output will be verified by a combination of wireline logs, core sampling, and testing that includes X-ray and scanning electron microscopy, cement logging, pH, and fluids testing.

This project has the primary objective of developing an Enhanced Analytical Simulation Tool (EASiTool) for the development of simplified reservoir models to predict pressure impact on CO2 injectivity and reservoir-storage capacity of geologic formations. The EASiTool will include three major features: (1) an advanced, closed-form, analytical solution for pressure-buildup calculations that is used to estimate both injectivity and reservoir-scale pressure elevation, in both closed- and open-boundary aquifers; (2) a simple geomechanical model coupled with a base model to evaluate and avoid the possibility of fracturing reservoir rocks during CO2 injection operations, which can account for rock deformation; and (3) a net-present-value based optimization algorithm to integrate the brine-management process so as to maximize stakeholders' profits, assuming carbon-storage credits.

ITN and Texas A&M University will study a lab-scale system for oxygen separation using magnetic fields gradients on polymer coated/encapsulated magnetic nanoparticles by pumping atmospheric air into a multicolumn chamber filled with magnetic nanoparticles coated in a proprietary polymer compound. The project will build and test a lab-scale oxygen separation system, perform computer simulation of magnetic force and magnetic field gradients, process optimization, economic analysis, and explore commercial opportunities.

This proposal will enable the development of a system that will synergistically capture carbon and treat wastewater at power plants. The system will have higher water recovery and treat more problematic water using less energy compared to state of the art technologies.

This proposal will enable the development of a system that will synergistically capture carbon and treat wastewater at power plants. The system will have higher water recovery and treat more problematic water using less energy compared to state of the art technologies.

Southern University and A&M proposes a novel integrated method to improve and design high entropy alloys (HEAs) for high temperature and high pressure gas turbine application and followed by experimental validation. The project will address the high temperature and high pressure oxidation resistance and low temperature ductility problems in materials research for coal energy conversion. Researchers will: perform molecular dynamics (MD)/Monte Carlo (MC) and interface energy HPC simulation on the HEA models to screen out the potential high temperature and high pressure oxidation resistant and low temperature ductile ODS HEA candidates; perform experiments on the high temperature and high pressure property of the most promising ODS HEA systems from the simulation; train students and integrate the materials design and HPC simulation into course work. The primary theoretical method of investigation is the ab initio molecular dynamics method based on the density functional theory.

The goal of this project is to develop an approach to screen ferritic steels, particularly 9-12Cr ferritic steel, for application in advanced ultrasupercritical power plants, based on physical properties of matrix BCC solid solution phase. The result will be used to construct a properties database which can be used to identify composition of new ferritic steel that are likely to succeed in high temperature AUSC applications.

This project will develop a systematic approach to quantify the relationships among the compositional, structural, and reactive properties of the mixed-metal oxide based Oxygen Carriers. This will lead to systematic and quantitative criteria for Oxygen Carrier development. Using these criteria, a combination of multi-scale modeling, metaheuristic optimization, and experiments will be used to design optimized Oxygen Carriers for coal Chemical Looping Combustion.

New developments in high-temperature, corrosion-resistant refractory alloys have shown promise of extended survival in environments that can exceed 1500ºC. The effect of grain boundaries (GBs), including quasi-liquid intergranular films (IGFs) formed at high temperatures, is an important limitation of an alloy applicability in such harsh environments. This project will focus on predicting the creep and associated microstructure evolution of W-based refractory alloys. The researchers will use a new concept, GB diagrams, to establish time-dependent creep resistance and associated microstructure evolution of GBs/IGFs controlled creep as a function of load, environment and temperature.

This Texas Engineering Experiment Station project aims to further the understanding of how turbulent flame speeds vary for syngas blends under realistic engine conditions and compile and demonstrate the validity of a comprehensive kinetics model that can predict laminar flame speed and ignition behavior of high-hydrogen content fuels in the presence of likely contaminants and diluents. The project will utilize both flame speed and shock tubes test facilities to obtain fundamental combustion data relevant for chemical kinetics modeling. Experiments include existing flame speed and shock-tube facilities as well as a new high-pressure turbulent flame speed with a capability up to 20 atmospheres with a controllable and repeatable level of turbulence.

The goal of this University of California, Irvine project is to develop design guides that can be used to predict jet flame flashback propensity as a function of pressure, temperature, fuel composition, free stream velocity, turbulence level, and fuel-air mixing profiles. This effort will lead to a better fundamental understanding of flashback tendencies and will also provide insight into strategies for preventing flashback.

The goal of this Virginia Tech project is to provide a better understanding of the combustor swirling flow and its effect on liner surface heat transfer in order to improve prediction methods and design practices in combustor liner cooling for low emissions combustors. The project will focus on the interaction between the hot swirling gases and the liner wall within a gas turbine combustor. This will support the development of more effective cooling schemes to maintain and improve combustor durability.

The aim of this Georgia Tech project is to develop a microstructure-sensitive crystal viscoplasticity (CVP) model for single-crystal Ni-base superalloys targeted for use in the hot gas path sections of industrial gas turbines (IGT). Microstructure degradation associated with aging critical to predicting long-term creep-fatigue interactions will be embedded into the CVP model through the precipitate morphology evolution by coupling the coarsening drivers and kinetics into the constitutive equations of the CVP model. This will be accomplished by systematically artificially aging the alloy under different stress conditions to determine the relationship between the size and morphology precipitates on the thermomechanical fatigue response. Long-term creep-fatigue interaction studies with specific emphasis on role of microstructure will be conducted on a single-crystal Ni-base superalloy with potential application to IGT.

This University of California, Irvine project will provide researchers with an improved mechanistic understanding of factors governing the performance of high-temperature abradable seals and degradation mechanisms unique to coal-derived syngas and high-hydrogen content (HHC)-based combustion environments. The ultimate goal for the research effort is to develop a knowledge base to support the design of coatings that retain optimal sealing characteristics and are more resistant to wear/attack mechanisms.

The project objectives are to investigate the impact of coal-derived syngas combustion environments on the performance, durability, and degradation of existing abradable coatings used on turbine shroud structures, and assess the potential for alternative materials sets to improve the performance of hot-section abradable seals in integrated gasification combined cycle (IGCC)-based gas turbine power plants. The proposed program will investigate several classes of abradable coatings (including metal and ceramic-based systems currently being utilized) under simulated exposures to syngas-based combustion environments to determine their relevant wear/abrasive recession behavior, hardness, stability under cyclic oxidation, and general thermo-mechanical behavior. The research is focused on correlating the measured thermo-mechanical behavior and controlled abrasive wear with the intrinsic properties of the multilayer coatings, process-controlled microstructural features, and service environment exposures.

This goal of this University of South Carolina project is to improve the turbine community's ability to predict the formation of nitrous oxides (NOx) in next generation high hydrogen turbines. The applicant will reach this goal by developing improved models that account for overlooked NOx formation pathways, which are currently unaccounted for because they are not well studied or understood.

The objective of this Purdue University project is to develop novel tools to predict creep-fatigue crack growth in nickel-based gas turbine alloys for stationary power applications by employing a framework of irreversible cohesive zone models (ICZM) together with a viscoplastic strain gradient (VPSG) continuum formulation. The present work investigates alloy IN 718. The ultimate goal is to create and validate a robust, multi-scale, mechanism-based model that quantitatively predicts creep-fatigue crack growth and failure in nickel-based gas turbine alloy IN 718. A successful model could be embedded into standard finite element software as an add-on analysis tool for gas turbine designers and thus greatly improve their capability to design safe gas turbines without excessive and costly over-design or unsafe under-design.

The primary objectives of this Purdue University project are to develop experimental methods, kinetic models, and numerical tools to quantify and predict the impact of exhaust gas recirculation (EGR) on NOx and CO emissions, combustion kinetics, radiation heat transfer, turbulent combustion, and combustion instabilities for HHC fuels by using laminar and turbulent flow reactors and gas turbine combustors operating at high temperatures and pressures. This project will provide detailed data for improving chemical kinetic models of EGR effects, supply insight into the effects of EGR on flame speeds and turbulent flame structure, and assess the impact of EGR on emissions in a high-pressure combustion test rig.

The objective of this University of North Dakota project is to research and develop three cooling methods for improved turbine airfoil cooling performance. The cooling technologies include incremental impingement for the leading edge, counter cooling for the pressure and suction surfaces, and sequential impingement for the pressure and suction surfaces of the vane. These methods are designed to improve the internal thermal effectiveness of the cooling air used before discharging the spent air onto the surface to form an optimal film cooling layer to thermally protect (i.e., reduce the heat load) the surface.

The overall objective of this University of Texas project is to develop predictive computational models for large eddy simulations (LES) for capturing flame flashback and propagation in high-hydrogen content fuels in high-pressure gas turbines. The focus will be on two key topics: behavior of high-pressure turbulent flames with and without equivalence ratio variations, and flashback propagation through a turbulent boundary layer. The predictive accuracy of the models for gas turbine operating conditions will be demonstrated using a combination of targeted experiments, legacy data, and high-resolution direct numerical simulation (DNS) data.

The proposed research will provide sensor deployment, coordination and networking algorithms for large numbers of sensors to ensure the safe, reliable, and robust operation of advanced energy systems. Specifically, the research will derive sensor performance metrics for heterogeneous sensor networks and will demonstrate effectiveness, scalability and reconfigurability of heterogeneous sensor networks in advanced power systems.

This work will focus on deriving, implementing, and testing bio-mimetic control and multi objective optimization algorithms that promote robust and reconfigurable performance in an advanced power system. The long-term objective of the proposed work is to provide a comprehensive solution to the scalable and robust multi-objective control of an advanced power system where no detailed system model is required for real-time control.

GTI will determine the technical feasibility of a novel hybrid metal/polymer membrane by depositing metal/alloy on the surface of a hydrogen-selective, temperature-resistant polybenzimidazole (PBI) polymer membrane substrate (provided by SRI International) to produce a hydrogen separation membrane with high hydrogen selectivity. Laboratory studies will establish the proof of concept of a novel metal-polymeric membrane. Additionally, GTI will obtain critical design data for an integrated multi-contaminant syngas removal process. A techno-economic analyses will integrate these technologies with an Aerojet Rocketdyne (PWR) gasifier using coal co-fed with natural gas to produce power, hydrogen, and liquid fuels. GTI will compare the integrated system with current hydrogen-from-coal production technologies.

This Southern Research Institute project will design, build, and test a novel steam reforming catalyst for converting tars and methane under high temperature and sulfur environments to increase the H2:CO ratio of a surrogate low-rank coal syngas. This will be performed at a lab-scale. This work is intended to demonstrate the potential commercial viability of catalytic steam reforming under severe contaminant environments to produce a cost-effective high H2 syngas from low-rank coals.

The GTI research team will evaluate and test a hybrid molten bed (HMB) gasification process for producing syngas from a coal/natural gas feed. The HMB gasification process potentially offers several benefits over conventional gasifiers including higher efficiency, higher yield of electricity or diesel, lower cost of electricity or diesel, lower costs for carbon capture, and lower capital costs due to simpler plant layout. The project team will conduct techno-economic analyses for plants based on conventional slagging gasification and HMB gasification producing both power and diesel and including carbon capture.

United Technologies Research Center (UTRC) will seamlessly embed a suite of sensors into the industrial gas turbine airfoil, thereby demonstrating additive manufacturing as a relevant process (when guided by physics-based models) for next generation gas turbines. The resulting smart part will: maintain its structural integrity, be remotely powered and sensed, and provide real-time diagnostics when coupled to a Health-Utilization-Monitoring System (HUMS).

The goal of this project is to demonstrate a high-temperature sensor concept for the monitoring of reaction conditions and health within slagging coal gasifiers. The technology will include the development of a smart refractory brick, which will contain embedded temperature, strain/stress, and spallation sensors throughout the volume of the refractory brick. The project will also develop a method to interconnect the sensors to the reactor exterior, where the sensor signals will be processed by low-power electronics and transmitted wirelessly to a central processing hub. The data processing and wireless transmitter hardware will be specifically designed to be isolated (with low power consumption) and will be adaptable to future implementation of energy-harvesting strategies for extended life. The collected data will be used for model-based estimation of refractory degradation, which can help to monitor the health of the refractory in real time.

This project is developing a system that can make high quality atmospheric near-surface CO2 measurements over an open area by using two prototype scanning sensors and coupling them with a series of retro-reflecting mirrors in a grid network. The prototype system will be deployed to the Zero Emissions Research and Technology (ZERT) field site for simulated leak tests of realistic scenarios expected for carbon storage sites. The ZERT test will deliver an extended data set for quantified validation of the precision and accuracy of the 2D concentration and flux maps. The system will be further refined and subsequently deployed to the Illinois Basin Decatur Program site for remote, autonomous monitoring at an active CO2 storage site.

Media and Process Technology Inc., in partnership with the University of Southern California and Technip Stone and Webster Process Technology Inc., will conduct testing of an innovative carbon dioxide (CO₂) capture process for coal-based integrated gasification combined cycle plants. The dual-stage membrane-based process combines two membrane technologies to accomplish cost-effective pre-combustion CO₂ capture. The process comprises a hydrogen (H₂)-selective carbon molecular sieve (CMS) membrane in a water-gas shift (WGS) membrane reactor (MR) for primary hydrogen recovery in tandem with a novel palladium (Pd)-based membrane for residual H₂ recovery. A high degree of H₂ recovery and CO₂ capture efficiency can be achieved with the two-step membrane process while avoiding the capital and compression costs associated with conventional two-stage operation. Laboratory-scale testing of the WGS/MR system will be performed using simulated synthesis gas (syngas) to establish a performance database that covers a range of operating conditions and to validate the existing mathematical model. A bench-scale (0.01 MWe) system capable of testing the CMS-WGS/MR and Pd-based membrane will be designed and fabricated, and field testing will be performed at the National Carbon Capture Center using real syngas. Data collected will be analyzed to evaluate gas separation efficiency and carbon monoxide conversion, as well as long-term material stability performance of the membranes. The field test results will form the input performance database for a rigorous engineering, economic, and environmental analysis for the process.

The project objective is the development of a novel CO2 capture hybrid process with cold temperature membrane operation. The project will optimize the commercial Air Liquide (AL) hollow fiber membrane bundles for CO2 recovery and and demonstrate performance in simulated and actual flue gas with a 0.1 MWe CO2 membrane field test unit. The project overall technical objectives and cost goals is to meet the DOE performance and cost targets of 90% CO2 capture, 95% CO2 purity and a capture cost of $40/tonne CO2.

The objective of this proposed research is to develop algorithms and methodologies for designing biomimetic control systems that utilize distributed intelligence for optimal control of advanced energy plants. The algorithms will be developed so as to make them applicable to other process and power plants for which plant models are available.

This project is developing a well testing technology for leakage detection in carbon storage reservoirs by developing the theoretical basis and numerical tools required for conducting harmonic pulse tests and results interpretation to assist in the validation of CO2 storage permanence. Laboratory experiments will be designed to validate the numerical tools and theory. This will be followed by further development of data assimilation and inversion algorithms for integrating the pulse test data to be demonstrated in the field.

The general focus of this Delphi project is the research and development of solid-oxide fuel cell (SOFC) cell, stack, and system technology. Specifically, Delphi will improve the performance, robustness, and reliability of their technology and systems while testing and evaluating pre-commercial systems in an environment simulating their entry into service product.

The objective of this Research Triangle Institute (RTI) project is to reduce the cost of coal gasification by reducing plant fuel, operating, and capital costs and increasing overall plant efficiency. The fundamental challenge to gasification for power generation and coal-to-liquids production is to achieve an overall syngas conversion process and production costs that are competitive with other conversion technologies and alternative feedstocks such as natural gas. Previous studies by the U.S, Department of Energy (DOE) and others have indicated that this challenge cannot be addressed by improving only one step in the overall gasification process. Researchers will assess the potential for substantially reducing the production cost of hydrogen (H2)-rich syngas via gasification with near-zero emissions due to the cumulative, synergistic improvements achieved when multiple advanced technologies are incorporated into the overall conversion process.

This project with the Energy & Environmental Research Center (EERC) of the University of North Dakota has the primary objective of evaluating and demonstrating novel methods for scalable, semipermanent seismic deployments that can be automated to show where and when a pressure front or CO2 plume passes a particular subsurface location. This concept uses autonomous node-recording instruments with a remote-controlled downhole and repeatable seismic source, in which an introduction of a small percentage of gas to the reservoir may change the character of the reservoir seismic reflection in a detectable way. Clever placement of source and receiver may allow the use of the seismic method as a yes/no switch to determine when the CO2 plume or pressure front has moved past a monitored location. Work is performed in North Dakota at the EERC with field work being performed at the Bell Creek field in Montana.

This LG Fuel Cell Systems project comprises laboratory development and testing of solid oxide fuel cell (SOFC) cells and stacks to advance and validate the reliability, robustness, and endurance of LG Fuel Cell Systems' (LGFCS) SOFC technology. LGFCS utilizes its integrated planar segmented-in-series SOFCs at pressures of up to seven atmospheres to achieve higher volumetric power densities. LGFCS will focus on advancing cell and stack materials and designs to create more stable and less expensive SOFC stacks and then test them at various scales to establish a preferred set of materials, which will undergo a block-scale metric test. The block test is the representative fuel cell module that forms the building blocks of the LGFCS SOFC power system. The fuel cell stacks will be tested as part of an integrated stack block in which all components needed to produce the flow, temperature, and compositional boundary conditions for the fuel cell stack are used. Consequently, the cells and stacks are evaluated using full-scale balance-of-plant components (reformer, exchanger, off-gas burner, circulators, and ducting) thus validating the performance of a complete integrated block (i.e., stacks and balance-of-plant components).

GE Global Research is advancing a novel carbon dioxide (CO₂) capture process that utilizes a phase-changing aminosilicone solvent (GAP-0) for post-combustion capture of CO₂ from coal-fired power plants. The solvent was initially evaluated in a previous Advanced Research Projects Agency-Energy project (DE-AR0000084). The GAP-0 solvent rapidly absorbs CO₂ in the 40 to 50^oC temperature range. The carbamate readily decarboxylates at higher temperatures with no degradation of the solvent, which decreases operating cost. A continuous bench-scale unit will be designed, constructed, and tested to evaluate the feasibility and scalability of the process. In the first phase of the project, initial process and cost models will be developed and the individual unit operations will be designed and built. In the second phase, testing will be performed on the individual unit operations to evaluate their performance. The data will be used to update the process and cost models. In the third phase, the integrated system will be operated under steady-state conditions, and the results will be used to update the models. A techno-economic assessment will be completed and a scale-up strategy developed.

The overall objective of this bench-scale project is to continue the advancement of the Recipient’s NAS CO2 Capture Process by addressing specific challenges facing the technical and economic potential of the process. This will be accomplished by demonstrating, at the bench-scale, the potential to reduce the thermal regeneration energy associated with the capture of CO2 from flue gas — a key criterion for achieving DOE’s Carbon Capture Program’s goal of >90 percent CO2 capture with a 95 percent CO2 product purity at a cost of <$40/tonne CO2 captured by 2025.

The goal of this Fuel Cell Energy project is the development of solid oxide fuel cell (SOFC) technology suitable for ultra-efficient central power generation systems (coal and natural gas fuels) featuring greater than 90% carbon dioxide capture. The development of this technology will significantly advance the nation's energy security and independence interests while simultaneously addressing environmental concerns, including greenhouse gas emissions and water usage. The specific technical objective of this project is to demonstrate, via analyses and testing, progress towards adequate stack life (= 4 years) and performance stability (= 0.2% per 1000 hours degradation) in a low-cost SOFC stack design. The work will focus on cell and stack materials and designs, balance-of-plant improvements to extend stack life and limit degradation, and performance evaluation covering operating conditions and fuel compositions anticipated for commercially-deployed systems. In support of performance evaluation under commercial conditions, this work includes the design, fabrication, siting, commissioning, and operation of a = 50 kWe proof-of-concept (fuel cell) module (PCM) power plant, based upon SOFC cell and stack technology developed to date by Fuel Cell Energy, Inc. (FCE) within the Office of Fossil Energy's Solid Oxide Fuel Cells program. The PCM system will be operated for at least 1000 hours on natural gas fuel at FCE's facility. The cost of the SOFC stack will be at or below the DOE's high-volume production cost targets (2011 $).

This project will demonstrate advanced manufacturing technologies for sapphire-based, high-temperature pressure sensors. Picosecond laser micromachining and spark plasma sintering will be used to achieve this goal. Project objectives include identifying laser ablation process variables, the characterization (and mitigation) of thermo-mechanical damage via the manufacturing process, and the development of cost/energy efficient procedures for rapid joining of components. The final result will be a fully packaged sapphire optical sensor capable of deployment in gas turbine applications at temperatures in excess of 1000 degrees Celsius (°C) and pressures up to 1000 pounds per square inch (psi).

The objective of this Pratt & Whitney Rocketdyne project is to develop fuel feed technology for high-pressure gasifiers that will result in significantly lower-cost coal gasification plant construction and/or operation for power production with carbon capture. Aerojet Rocketdyne will conduct dry solids pump (DSP) feed system test operations at 400 tons per day (up to 600 tons per day [tpd]), collect and analyze the resultant data, and develop and update the models needed to prepare a conceptual design of a 1000 tpd DSP operation. This project will provide researchers with the test data, analytical models, and operational experience needed to confidently design a 1000 tpd high-pressure DSP system.

This three-year, bench-scale project is focused on evaluating the improved performance of a next-generation Biocatalyst Delivery System (BDS) and non-volatile solvent blend (AKM24) by incorporating the process- and solvent-related advances into Akermin's existing 500 SLPM bench unit and conducting integrated bench-scale testing at the National Carbon Capture Center (NCCC), while demonstrating significant progress toward achievement of the DOE cost target of less than $40/ton of CO2 captured. Akermin shall optimize the performance of a commercial prototype BDS that enables on-stream replacement of the biocatalyst; complete detailed design, engineering, and costing of the bench unit modifications; modify the existing 500 SLPM bench unit to incorporate the next-generation BDS; operate the modified bench unit on actual coal-derived flue gas at the NCCC; and complete a techno-economic analysis of the next-generation Akermin process.

SRI International, in collaboration with OLI Systems, Inc., Aqueous Systems ApS, Politecnico di Milano (POLIMI), and Stanford University, will advance the development of a novel ammonia-based mixed-salt solvent process for carbon dioxide (CO2) capture from coal-fired power plants by designing and testing a bench-scale (approximately 100 kW) CO2 capture system. The mixed-salt technology combines ammonium and potassium carbonates for enhanced CO2 capture efficiency, high CO2 loading capacity, and reduced energy consumption. The high operating pressure of the solvent regenerator also has the potential to reduce the CO2 compression costs. The technology consists of a two-stage absorber system with a single stage regenerator. To improve process performance, the absorber conditions will be optimized using two individual absorbers before testing the single two-stage absorber. Individual absorber and regenerator tests will be performed in a semi-continuous mode to collect data on solvent concentration, CO2 capture efficiency, water usage, and ammonia loss. Bench-scale testing of the continuous, integrated two-stage absorber system will be performed using simulated flue gas. Data collected will be used to complete thermodynamic modeling and a techno-economic analysis for integration of the mixed-salt technology into a full-scale power plant.

In this project, researchers will develop and demonstrate a thermionic element; develop a functional Generation 1 temperature and pressure sensor and validate its performance; develop and demonstrate the pathway to a Generation 2 multi-parameter wireless sensor; and support the commercialization of the harsh environment adaptable thermionic (HEAT) sensor technology. The Generation 1 HEAT sensor will integrate thermionic elements into a functional package that measures temperature and pressure over a range of environmental conditions and amplifies the resulting signals for data transmission over wire. The Generation 2 HEAT sensor will expand the capability to measure additional strain, flux, and flowrate process parameters, as well as incorporate a completely wireless configuration. The proposed HEAT sensor platform is a new technology useful for the extreme conditions at which advanced energy system processes will operate. This sensor platform will enable a new level of process monitoring and control, contributing significantly to the overall operational performance and reliability of advanced power generation plants.

TDA Research, Inc. (TDA) has teamed with CDM Smith, Inc., Gas Technology Institute, the University of Alberta, the University of California Irvine, and Sinopec to advance their novel sorbent-based pre-combustion carbon capture technology through pilot-scale testing using a slipstream of synthesis gas (syngas) from an operating gasifier. TDA's high-temperature pressure swing adsorption (PSA)-based process uses an advanced physical adsorbent consisting of a mesoporous carbon grafted with surface functional groups that selectively removes carbon dioxide (CO₂) from syngas via physical adsorption at temperatures above the dew point of the gas. This low-cost, high-capacity regenerable sorbent was evaluated previously by TDA through bench-scale and slipstream testing and achieved a high CO₂ removal rate of greater than 95 percent for more than 10,000 adsorption/desorption cycles. In this project, research will include scaled-up production of the sorbent; improvement of the PSA cycle sequence using adsorption modeling and optimization of the sorbent reactor design through computational fluid dynamics analysis; long-term sorbent life evaluation in a bench-scale setup of up to 60,000 cycles; design and fabrication of a 0.1-MWe pilot-scale testing unit that contains eight sorbent reactors; design of a CO₂ purification sub-system; and two separate field tests on the fabricated pilot-scale unit to measure the sorbent's performance and process efficiency. The first pilot test will be conducted at the Power Systems Demonstration Facility at the National Carbon Capture Center, and the second test will be conducted at Sinopec's integrated gasification combined cycle (IGCC) plant in China. These facilities use different types of gasifiers (air-blown transport gasifier vs. oxygen-blown gasifier) and feedstocks (low-rank coals vs. petcoke), which will allow researchers to assess process efficacy in very different gas streams. Based on the field test results and process model simulations, a techno-economic evaluation will be completed to calculate the impact of the CO₂ capture system on plant efficiency and the cost of electricity (COE).

Membrane Technology and Research, Inc. (MTR) and The University of Texas at Austin (UT-Austin) will construct and evaluate a hybrid membrane-absorption process system for capturing carbon dioxide (CO₂) from coal-fired power plants. The system will combine Polaris^TM membranes (high-permeance, low pressure-drop, plate-and-frame modules) developed by MTR, and an improved amine solvent-based capture system developed by UT-Austin that uses a piperazine solvent and advanced high-temperature and high-pressure regeneration (high thermal stability, rapid CO₂ absorption rate, and low oxidative degradation). In this project, a process simulation model will be developed for the hybrid process and both series and parallel configurations of the hybrid process will be evaluated. Large-area, plate-and-frame membrane modules will be fabricated and tested to analyze pressure drop performance and permeance. Parametric tests will be performed separately on MTR's membrane test unit and on UT-Austin's absorption/stripper system under a full range of operating conditions for both series and parallel designs. These test results will be incorporated into the hybrid process model to determine the optimal mode of operation of an integrated membrane-absorption system. Integrated testing with MTR's membrane test skid will performed on the hybrid capture system at UT-Austin's Separations Research Program (SRP) 0.1 MWe pilot plant. Process models will be updated based on the pilot test results and a scaled-up model as well as a final techno-economic analysis for a full-size power plant will be developed.

ION Engineering, LLC, along with their partners, aim to advance ION’s solvent-based post-combustion CO2 capture process through pilot-scale testing with coal-fired flue gas. Testing of the second-generation solvent will first be conducted at the National Carbon Capture Center (NCCC) at small pilot scale to capture CO2 from a flue gas stream equivalent to a scale of 0.6 MWe power plant. The solvent will subsequently be tested at the Technology Center Mongstad in a 12 MWe pilot test unit to capture CO2 from an industrial flue gas to simulate coal-fired power generation. ION will conduct parametric and continuous long-term testing of the advanced solvent and analyze solvent performance, degradation, and air emissions under various steady-state operational conditions. A detailed final techno-economic analysis and an environmental, health, and safety assessment will be completed. ION will evaluate the solvent’s ability to meet or exceed DOE’s Carbon Capture Program goal for second generation solvents of 90 percent CO2 capture with a 95 percent CO2 product purity at a cost of $40/tonne CO2 captured by 2025.

The overall objective of this project is to design, construct, and operate a slipstream-scale process for a novel aminosilicone-based CO2-capture solvent. The project will establish scalability and techno-economic feasibility of using an aminosilicone-based CO2-capture solvent for post-combustion capture of CO2 from coal-fired power plants at less than $40/tonne of CO2 captured with 90 percent CO2 capture and 95 percent CO2 purity.

This project will develop cost effective monitoring tools that can be used to demonstrate safe, permanent storage of CO2 in deep geologic formations. Under this project, EPRI will conduct field trials to extend the use of fiber optics to new and innovative in situ measurements and applications supporting CO2 storage and utilization (Enhanced Oil Recovery), including detection of CO2 flow, migration, and seismic monitoring. The project uses Distributed Acoustic Sensor (DAS) arrays to detect and image the CO2 plume using seismic methods. In addition, the sensors have heat-pulse monitoring capability using Distributed Temperature Sensing (DTS) to detect vertical CO2 leakage along the wellbore and flow outside of the casing. EPRI will work on designing, fabricating, and acquiring monitoring data from fiber optic cable assemblies to be installed in wells at up to two field facilities.

Orbital ATK, Inc., along with their partners, are continuing the development of a novel Inertial Carbon Dioxide Extraction System (ICES) for carbon dioxide (CO₂) capture from coal-fired power plants through lab- and bench-scale testing. The ICES converts vapor-phase CO₂ contained in flue gas to a solid (dry ice) using supersonic expansion followed by inertial separation. This method utilizes a unique aero-thermodynamic inertial separation device, in which flue gas is directed to a converging-diverging nozzle and expanded to supersonic velocities, resulting in the desublimation and separation of CO₂. Solid CO₂ particle growth methods will be tested at lab scale to obtain a condensed CO₂ particle size required to support efficient migration in the ICES turning duct. Computational fluid dynamics modeling for the capture duct and diffuser will be performed to evaluate configurations of the bench-scale unit, validate laboratory test results, and predict performance of the full-scale ICES unit. The capture duct will be tested at bench-scale while controlling CO₂ particle size to measure the capture efficiency of migrated particles. The diffuser will be tested to evaluate diffusion of CO₂-depleted flue gas to atmospheric pressure. A series of bench-scale tests will be conducted to validate the effectiveness of several particle growth strategies. An update to the techno-economic analysis will be completed.

This TDA project will demonstrate the technical and economic viability of an integrated water-gas-shift (WGS) catalyst/CO2 removal/thermal management system for an IGCC power plant and a coal to liquids (CTL) plant. It will explore the best reactor design option that allows for the integration of a proven high temperature CO2 adsorbent and a commercial WGS catalyst with improved thermal management. It will also use CFD modeling to assess the potential of using filter tubes for direct evaporative cooling while simultaneously supplying the process with the reactant steam. New reactors will be fabricated to evaluate the performance of the integrated system, first in the bench-scale tests and then in a field demonstration using actual coal-derived synthesis gas.

This Air Products and Chemicals, Inc. (APCI) project will advance ion transport membrane (ITM) technology further towards the ITM Oxygen Development Facility, a 2,000 TPD demonstration-scale test unit. In addition, technical risks will be reduced through economics studies to assess cost and environmental benefits of the ITM system, which is expected to cost 30% less than conventional cryogenic oxygen separation technology. APCI has a co-current ITM project FT40343.

The objective of this Ohio State University project is to further demonstrate the technical and economic advantages of chemical looping gasification (CLG) for power generation and for synthesis of transportation fuels and other high value chemicals from coal. Specifically, the research team aims to (1) improve oxygen carrier performance, (2) demonstrate at bench-scale that the CLG process can achieve greater than 98 percent coal conversion, (3) demonstrate the effects and fates of contaminants, (4) develop a sub-pilot-scale cold-flow model, and (5) provide a comparative techno-economic analysis that establishes the feasibility and attractiveness of the CLG system.

Oklahoma State University (OSU) is conducting a three-year research and development project that will develop and demonstrate an integrated monitoring system that is capable of directly detecting and quantifying seepage of CO2 and CH4; into the soil and atmosphere. The approach employs in-ground and surface sensors and unmanned aerial vehicles (UAV) to collect data. OSU proposes to develop the CO2 and CH4; sensors and the UAV platform at OSU facilities. The integrated system will then be installed, tested, and optimized at a field site, the Farnsworth Unit (FWU), site of the Southwest Regional Partnership on Carbon Sequestration (SWP) Phase III field site.

The research is developing and testing a robust, cost-effective sensor array for long-term monitoring of CO2 inventories in deep geologic formations using controlled source electromagnetic methods (CSEM) to measure the electrical properties of CO2 reservoirs. The CSEM system will be field deployed to the Ketzin, Germany pilot injection site in a three phase testing program.

The real-time, accurate and reliable monitoring of temperatures at distributed locations can further revolutionize technologies such as the unique integrated gasification combined cycle configuration of turbines and the ultra-super critical steam cycle designs. The proposed sapphire fiber waveguide design will overcome the harsh environment challenges that severely limit the integration of mature optical fiber sensing technologies in new power plant control systems. A new modal reduction waveguide design will take advantage of the high temperature stability and corrosion resistance of sapphire and result in a paradigm shift in ultra-high temperature sensing. A novel and precise etching technique will significantly reduce ( >50%) the mode volume in a robust and truly unique sapphire fiber.

This research project aims to optimize advanced 3-D manufacturing processes for embedded sensors in energy system components, characterizing the performance and properties of these smart parts, and assessing the feasibility of applying these parts in harsh energy system environments. Specific project objectives are to (1) fabricate energy system related components with embedded sensors, (2) evaluate the mechanical properties and sensing functionalities of the smart parts with embedded piezoceramic sensors, and (3) assess in-situ sensing capability of energy system parts. This research effort will not only contribute to designing and fabricating parts, but also to determining the smart part's durability, repeatability, and stability by testing it in realistic energy environments.

This project is developing a multi-parameter system for the highly sensitive and accurate detection of carbon dioxide in groundwater. The stand-alone system will include novel distributed fiber optic sensors for CO2, pH, and salinity, as well as a commercially available distributed sensor for temperature. The sensors will be fabricated by coating optical fibers with chemically-sensitive indicator-doped polymers, thus rendering the entire length of the optical fiber a sensor capable of covering large areas in distances of thousands of feet. The project involves developing two novel sensitive claddings for salinity and pH sensing. Once developed, optical cables sensitive to each parameter will be produced. Those cables will be combined with a CO2 sensitive cladded fiber as well as an off the shelf fiber optic temperature sensor to produce a real time monitoring network to be used for CO2 storage monitoring, verification, accounting (MVA), and assessment operations, which will be validated in the field.

The Gas Technology Institute (GTI), along with Air Liquide Advanced Separations, will continue development of a novel nanoporous, super-hydrophobic contactor process for solvent-based post-combustion CO₂ capture from coal-fired power plants. The polyether ether ketone (PEEK) hollow fiber contactor (HFC) will be advanced from bench-scale to pilot-scale testing. The PEEK HFC process takes advantage of both the compact nature of an HFC process and the high selectivity of an absorption process. In the process, CO₂-containing flue gas passes through one side of the PEEK HFC, while an advanced CO₂-selective solvent flows on the other side. The CO₂ permeates through the hollow fiber contactor pores and is chemically absorbed into the solvent. The CO₂ rich solvent is regenerated in a second PEEK HFC module. Pilot-scale testing will be conducted with commercial size 8-inch diameter modules on 0.5 megawatt electrical (MWe) equivalent of coal-derived flue gas at the National Carbon Capture Center (NCCC). Continuous steady-state operation will be conducted for a minimum of two months to collect data necessary for further process scale-up. A techno-economic analysis and an environmental, health, and safety assessment will be completed to validate the potential of the PEEK HFC process to achieve DOE’s performance goals of a 90 percent CO₂ capture rate with 95 percent CO₂ purity at a cost of no more than $40 per tonne of CO₂ captured by 2020.

The team, partnering with leading solids-to-solids heat exchanger company Solex Thermal, will advance carbon capture technologies with solid sorbents by reducing the energy penalty and overall cost for CO2 capture by recovering heat generated by the sorbent during the capture process.

The project will demonstrate the ability of the CAER catalyzed, advanced amine solvent to reduce the energy of regeneration and show higher mass transfer (lower capital) for post-combustion CO2 capture. Using an integrated 0.1 MWth bench-scale testing unit with coal derived flue gas located at the CAER facility, optimized process energy and mass transfer rate will be determined using both the advanced amine solvent and the catalyzed advanced amine through parametric testing. A comparison will be made to the operation of MEA using the same apparatus to allow comparison to the NETL reference case. A long-term test campaign will be conducted to show the ability of the solvent and catalyst to tolerate the high temperature stripping conditions utilized by the CAER process and the contaminants present in flue gas. Heavy metal removal will be demonstrated. Finally, a membrane solvent dewatering process will be integrated into the bench-scale unit and shown to further reduce process energy by increasing solution CO2 partial pressure. The bench-scale testing along with fundamental data available from CAER research (during and prior to the project period) will be used to develop a detailed techno-economic process model including a rate-based Aspen Plus process simulation at the 550 MW scale and an EH&S assessment of the CAER solvent and process.

SRI International has teamed with Generon IGS, Enerfex, Inc., Electric Power Research Institute, and PBI Performance Products to further develop a high-temperature, membrane-based, pre-combustion carbon capture technology for integrated gasification combined cycle power plants. The separation process utilizes a high-temperature stable polybenzimidazole (PBI) polymer to separate coal-derived synthesis gas (syngas) at elevated temperatures (200 degrees C to 250 degrees C) into a hydrogen (H₂)-rich permeate stream and a retentate stream that consists mainly of high-pressure carbon dioxide (CO₂). The PBI polymer will be fabricated into hollow asymmetric fibers, assembled into membrane modules, and inserted into high-pressure vessels for inclusion in a 50-kilowatt thermal capacity bench-scale unit that will be tested at the National Carbon Capture Center (NCCC). Short-term and long-duration tests will be performed using a 50-lb/hr syngas stream from the gasifier at NCCC to evaluate membrane stability, H₂/CO₂ selectivity, and H₂ permeance. Collected data will be used to complete design and engineering studies of a full-scale plant incorporating the PBI membrane-based process. A detailed techno-economic analysis will also be completed.

The overall goal of the project is to demonstrate SRI International's post-combustion capture technology by incorporating the advanced carbon sorbent-based process in a 1 MWe slipstream pilot plant and achieving at least 90% carbon dioxide (CO2) removal from coal-derived flue gas while demonstrating significant progress toward achievement of the DOE cost target of less than $40/ton of CO2 captured. To accomplish this, the project team, which includes Linde LLC, ATMI, Inc., Linde Engineering North America (LENA), Linde Engineering Dresden (LEDD), and the Electric Power Research Institute (EPRI) will design, build, and operate the pilot plant at a coal-fired power plant host site providing the flue gas as a slipstream.

Aspen Aerogels, Inc. has teamed with the University of Akron and others to develop and test aerogels, an innovative type of solid sorbent, for carbon dioxide (CO₂) capture from coal-fired power plants. The aerogels have high surface area and porosity and excellent hydrophobicity for resisting performance degradation from moisture and flue gas contaminants, resulting in reduced operating costs for CO₂ capture. Aspen Aerogels aims to improve CO₂ capture performance of the best-performing amine functionalized aerogel (AFA) formulations developed under previous research (Small Business Innovation Research [SBIR] grant DE-SC0004289) and to optimize the AFA production and pelletization processes. The project will focus on bench-scale testing to optimize the most promising aerogel formulations developed for maximized working capacity and robust cyclic stability in flue gas conditions. The University of Akron will develop binder formulations, pellet production methods, and post-treatment technology for increased resistance to flue gas contaminants. ADA will assess the performance of the sorbent in bead form and in pellet form by analyzing sorption isotherms, selectivity to flue gas contaminants, crush strength, attrition, fluidized bed properties, and heat transfer coefficients for the adsorption/desorption process. The hydrodynamic and heat transfer properties of the pelletized sorbent will be evaluated in a bench-scale fluidized bed reactor at ADA. Scale-up methods for the sorbent will be explored at the University of Akron. ADA will also perform a techno-economic assessment of the aerogel sorbent technology for CO₂ capture from coal-fired power plants.

In this project, Air Products and Chemicals Inc. (ACPI) will test a two-bed pressure swing adsorption (PSA) unit on a slipstream of authentic, high-hydrogen syngas based on low-rank coal at the National Carbon Capture Center (NCCC); also a multi-bed process development unit (PDU) will be operated, refining the reliability of predictions of PSA performance at commercial scale. The information obtained from the two-bed PSA unit and the PDU will be combined to build a techno-economic assessment (TEA) of Sour PSA utilization for methanol production with 90% carbon capture, as well as to update techno-economic assessments of the technology for integrated gasification and combined cycle (IGCC). The TEA shall incorporate NETL's Cost and Performance Baseline for Fossil Energy Plants and the guidelines delineated in the funding opportunity announcement. The overarching objectives of the FOA that this project was selected from are to reduce the cost of coal conversion via gasification through (1) reducing plant capital costs; (2) reducing fuel and operations costs; and (3) increasing overall plant efficiency.

Develop a protective aluminide/alumina coating for steel alloys used in Advanced Ultra-Supercritical (A-USC) power-plants.

TDA Research, Inc. is advancing their sorbent-based post-combustion carbon dioxide (CO₂) capture process by designing and building a pilot-scale unit and testing it with a 0.5-MWe slipstream of flue gas at the National Carbon Capture Center (NCCC). TDA's process is based on an alkalized alumina adsorbent that uses low-pressure steam for desorption and operates at near atmospheric pressure, reducing the cost of CO₂ capture compared to commercially available amine-based and other solid sorbent-based systems. Previous bench-scale testing of the process using real coal-derived flue gas showed that TDA's sorbent can achieve greater than 90 percent CO₂ capture with stable CO₂ loading. In this project, TDA's sorbent-based process will be tested at NCCC under realistic conditions for continuous long-term operation to evaluate the technical and economic feasibility of the technology for further scale up. Parametric testing will be conducted for 1.5 months to determine the optimum operating conditions and steady-state testing will be performed for a minimum of 2 months. Scale-up production of the sorbent will also be performed. A detailed techno-economic analysis based on integration with a nominal 550-MWe power plant will be completed based on pilot-scale test results.

YSZ has been identified as a potential barrier to prevent alkali earths in the seal glass from reacting with the interconnect. To be successful, YSZ with a high degree of structural perfection and uniformity must be formed in an extremely cost effective way over rough interconnect surfaces. Sonata's approach will leverage atomic layer deposition (ALD) to form such a YSZ barrier layer. The technical objective is to demonstrate high integrity YSZ thin film barriers with high density and conformality, using a simple tooling/masking technique to permit very large production lot sizes of 1000-2000 interconnects per run with the barrier limited to the perimeter area of the interconnect.

A thin protective YSZ layer separating the ferritic steel interconnects from the compliant glass will be deposited using ISL's low cost SOFSeal deposition by CSD (sol-gel). Commercial organometallic/metallorganic raw materials can be easily blended in either aqueous or organic solvent based form. Layer thickness can be adjusted by dilution with the appropriate solvent and mask thickness. Methods for applying the film will be evaluated including doctor blading, silk screening, and spraying using a masking technique to deposit in selective areas.

The overall objective of the project is to develop a novel distributed optical fiber sensing system for real-time monitoring and optimization of spatial and temporal distributions of high temperature profiles in fossil power plant boilers. Specific objectives are to: 1) Establish a boiler furnace temperature distribution model and guide the design of the sensing system; 2) Develop the sensors with one active sensing element on each fiber as well as a temperature distribution reconstruction algorithm for proof-of-concept; 3) Develop the distributed sensing system to integrate multiple active sensing elements on a single optical fiber. The entire sensing system, after being fully integrated and tested in the university labs, will be tested on Alstom combustion test facility.

TDA Research, Inc. (TDA), in collaboration with Membrane Technology Research Corporation and the University of California, Irvine proposes to develop a low cost, high capacity sorbent that will integrate into a membrane-sorbent hybrid post-combustion carbon capture system to remove CO2 from coal-fired power plant effluents.

This program aims to develop a new type of low cost, robust metal-ceramic coaxial cable (MCCC) Fabry-Perot interferometer (FPI) sensor and demonstrate the capability of cascading a series of FPIs in a single MCCC for real-time distributed monitoring of temperature up to 1000 degrees Celsius. The sensor will be operated in various gas environments relevant to coal-based power production to examine its stability in practical applications.

The project will develop a novel nanomaterial to efficiently capture CO2 from the flue gas of fossil energy power generation systems by: 1) Establishing a knowledge base on the synthesis of titanium dioxide (TiO2) nanotubes and adsorption characteristics of Polyethylenimine (PEI) and also the various protocols available for the impregnation of PEI, 2) Developing optimized protocols for synthesis of TiO2 nanotubes impregnated with PEI, 3) Characterizing the impregnated nanotubes and using them for refining synthesis parameters such as temperature, concentration, and time, 4) Developing computational fluid dynamic (CFD) simulations in order to optimize the reactor conditions for high carbon capture efficiency, 4) Demonstrating the carbon capture efficiency of impregnated TiO2 tubes under various environmental conditions such as temperature and concentration, and 5) Establishing a validated CFD model and a standard operating procedure for carbon capture using PEI impregnated TiO2 nanotubes.

The objective of this project is to develop carbon nanotube (CNT)-ceramic (C) composite structures, in which vertically aligned (VA) carbon nanotubes are embedded in ceramic matrices for hot electrode applications such as magneto-hydrodynamic (MHD) power systems. Four objectives will be accomplished as follows: (1) Super growth of vertically aligned (VA) CNT carpets, (2) Fabrication of CNT-boron nitride (BN) composite structures, (3) Stability and resistance studies of the CNT-BN composite structures, and (4) Thermionic emissions from the CNT-BN composite structures.

Developments in nano-engineered materials have resulted in the discovery of a number of new materials which may have beneficial applications for CO2 capture. This project aims to develop and evaluate silica-based nanostructure platforms containing amine-based solid sorbents for post-combustion carbon dioxide (CO2) capture. The fabrication process will allow for significantly enhanced porosity and surface area, which will allow for increased CO2 adsorption capacity. In addition, the use of inexpensive raw materials and low-cost synthetic processes will position these platforms as a competitive solid sorbent for replacement of solution-based amine scrubbing technologies used in post-combustion CO2 capture.

This research effort will apply advanced computational techniques to develop reduced order models in the case of reacting multiphase flows, based on high fidelity numerical simulation of gas-solids flow structures in risers and vertical columns obtained by the Multiphase Flow with Interphase eXchange (MFiX) software. The project will also generate numerical data necessary for validation of the models for multiple fluidization regimes; expose minority students to scientific research in the field of fluid dynamics of gas-solids flow systems; and maintain and upgrade the educational, training, and research capabilities of Florida International University.

University of Texas Arlington will develop wireless antenna sensors to provide distributed sensing of temperature, strain, and soot accumulation inside a coal-fired boiler. The objectives include (1) a methodology to realize low-cost antenna sensor arrays that can withstand high-temperature and high-pressure environment, (2) a wireless interrogation technique that can remotely interrogate the sensors at long distance with high resolution, and (3) material and fabrication recipes for synthesizing flexible dielectric substrates with controlled dielectric properties.

This project will synthesize and characterize ultra-high surface area metal organic framework (MOF) materials for CO2 adsorption. This 3-yr research effort will consist of synthesizing MOFs with organic linkers as well as nitrogen-containing pyrazine linkers and evaluate them based on CO2 adsorption properties, framework structure and composition (such as metal content and elemental analysis), surface area, pore size, and thermal stability. The evaluation methods will include X-ray crystallography, powder X-ray diffraction (PXRD), thermogravimetric analysis, infrared spectroscopy, and other advanced techniques. The down selected CO2 adsorption material from this research will be used for CO2 capture and sequestration application.

University of Texas at Austin is developing screening tools for improved understanding of reservoir geomechanical processes and conditions related to carbon dioxide (CO2) storage including faults, fractures, and caprock flaws. Geomechanical rock experiments and computational methods using modeling, simulations, history matching, and uncertainty quantification will be conducted and applied to two field demonstration sites to generate and validate the geomechanical screening tools.

LG Fuel Cell Systems (LGFCS) will focus on the evolution of the LGFCS stack (integrated planar segmented-in-series solid oxide fuel cells (SOFCs) at pressures up to seven atmospheres) and block technology to include in-stack reforming. In addition, this project will address further design optimization of dense ceramic parts, ceramic/glasses and the porous substrates. All the stack design improvements are aimed at being better suited to a more automated manufacturing and assembly operation with improved yields. LGFCS will validate new strip designs that enable incorporation of maximum levels of in-stack reforming and redesigned ceramic components and substrates that can be produced in volume at lower cost and which further improve fuel flow distribution throughout the stack. Extensive multi-physics-based modeling will be performed and validated to probe the thermal stress state imposed on the ceramic strip components over the range of stack designs and operating parameters to insure that structural reliability of the ceramic structure is not compromised by the inclusion and extent of in-stack reforming selected for the product. In-stack reforming will be initially validated within the single-block pressurized test rigs that replicate the product cycle and conditions. A follow-on test in a triple-block rig will also be conducted. This project will also include full system testing for a planned 22 week test schedule of all the subsystems of the LGFCS megawatt-scale product. This project will use active layers developed in a previous LGFCS DOE contract, FE0012077, having lower ASR and improved durability to construct strip components for use in the triple-block test with in-stack reforming. Improved seals with adjusted thermal expansions will be utilized.

This SBIR project aims to establish cost effective and scalable processes for preparing advanced SOFC cathode materials having core-shell composite microstructures. The project leverages results of recent DOE sponsored research and will deliver high performance cathode materials, providing drop-in process capability to SOFC manufacturers.

Metna Co. is developing scalable, economical, and convenient methods of delivering carbon dioxide (CO₂) to concrete, and is tailoring the chemistry of concrete to make beneficial use of large CO₂ volumes toward achieving enhanced performance, economic sustainability, and energy-efficiency attributes. The main thrust of this project is to develop robust and commercially viable methods for chemical binding of large CO₂ volumes in concrete while realizing balanced gains in material properties. Concrete materials incorporating two different inorganic binders based on calcium silicate hydrate (Portland cement) and alkali aluminosilicate hydrate (geopolymer cement) are being investigated. In Phase I, engineering tests performed on concrete materials confirmed that sorption of CO₂ into reactive cementitious materials yields significant gains in the mechanical, barrier, and durability characteristics of concrete and can be accomplished by simple and low-cost modification of the existing milling step in the production of cementitious materials. Phase II work includes adapting the technology for use with broader selections of raw materials and additives; devising refined chemistries for selective sorption of CO₂ from flue gas; scale-up of the process in an industrial manufacturing plant where cement and slag processing is accompanied with flue gas emission; and conducting life-cycle analyses to further verify and quantify the benefits of the technology in terms of CO₂ storage and emission control, energy and cost savings, and enhancing the longevity, efficiency and life-cycle economy of the concrete-based infrastructure.

This project worked to develop a further understanding of how shales respond to carbon dioxide (CO₂)-induced deformation and reactions. Research was conducted to quantify CO₂ transmissivity and the development of acoustic methods for detecting damage to CO₂-saturated caprock through in-situ experimental studies of shale. This project provided tools to identify damaged shale caprock and a means of determining if CO₂ has migrated through the caprock.

The University of Connecticut will develop and validate reliable, cost-effective approaches for minimizing/mitigating solid oxide fuel cell (SOFC) cathode (lanthanum strontium manganite [LSM] and lanthanum strontium cobalt ferrite [LSCF]) degradation through the incorporation of reliable materials and architectures to inhibit long-term detrimental solid-solid and solid-gas interactions. This work will develop and demonstrate the viability of the application of a cost-effective chromium getter to capture the chromium species originating from the metallic stack and balance-of-plant components. Cathode compositions will be modified to control and prevent oxide segregation and compound formation at the surface and interfaces during air exposure. Cathode contact layer modification will be developed to avoid chromium poisoning originating from metallic interconnects.

Under this project the Colorado School of Mines is developing a quantitative approach for understanding and predicting geomechanical effects from large-scale carbon dioxide (CO2) injection, including rock deformation and fracturing. Through laboratory analysis and numerical modeling, the project is assessing and validating CO2 flow, storage potential, and the risk of leakage in porous and fractured reservoirs.

Fuel Cell Energy Inc. (FCE) and its subsidiary Versa Power Systems Inc. (VPS) will team to improve the reliability of solid oxide fuel cell (SOFC) systems by achieving an SOFC stack power degradation rate of less than 1.5 percent per 1000 hours in a 100 kilowatt (kW) (125 kW Peak) Modular Power Block (MPB) stand-alone power system under thermally self-sustained normal operating conditions. The potential for a high-volume SOFC stack production cost below the DOE target of $225 per kW will also be validated. The scope of work will focus on SOFC stack reliability and endurance, especially in actual system operation. The project team will use a multi-pronged approach including materials development, manufacturing process quality, robust and reliable stack design, novelty in-system design and incorporation of lessons learned from prior fuel cell systems operation. The project will address one of the key obstacles to commercialization of the SOFC, the high degradation of the fuel cell in presence of excessive moisture in air leading to production of chromium species in the cathode. Extensive research will be performed to discover mitigation technologies including chromium-tolerant cell materials and novel interconnect coatings. This work builds on previous DOE contract FE0011691.

West Virginia University (WVU) will team with Northwestern University and Fuel Cell Energy (FCE) to improve the stability and performance of solid oxide fuel cell (SOFC) cathodes through development of a scalable and cost-effective electrophoretic deposition (EPD) process. EPD will deposit dense barrier layers, with little or no porosity, between the electrolyte and cathode. Identification of optimal barrier layer composition and thickness will be researched including an investigation of the interaction between doped ceria barrier layers in SOFC cathodes and their effect on oxygen reduction reaction kinetics, electrochemical performance, and long-term stability. A preliminary techno-economic analysis of the EPD barrier layer compared to other coating methods will be performed.

Boston University will team with Fuel Cell Energy to understand the detailed mechanisms of chromium poisoning in the cathode of solid oxide fuel cells (SOFCs) and provide solutions that eliminate or mitigate chromium poisoning in cathodes, reducing or eliminating its effects on SOFC power systems. The project includes fabrication and testing of cells, modeling the thermodynamics and transport phenomena of chromium poisoning, and implementation of solutions to chromium poisoning at the single-cell level.

A collaborative effort among Virginia Polytechnic Institute and State University (Virginia Tech), Northeastern University, the University of Delaware, and Utah State University will provide research and development of catalysts to improve operation of coal gasifiers. The work involves experiments, kinetic modeling, and computational fluid dynamics (CFD) that will address and make recommendations for advanced catalytic gasification of coal and coal-biomass mixtures. The novel approach of this project will be the use of red mud catalyst with sub-bituminous coal to effectively gasify coal and produce a cleaner syngas with elevated levels of hydrogen without the negative by-products of methane, sulfur compounds, and chlorine. The outcome of this work will be the characterization of the chemical kinetics and reaction mechanisms and the development of a set of models that can be integrated into MFIX, OpenFOAM and other CFD modeling environments. Most importantly, this work will demonstrate advancements in catalytic gasification of low-rank coal that will promote optimum syngas composition for polygeneration of electricity and other fuels or chemicals.

Princeton University developed new modeling capabilities for simulation of carbon dioxide (CO₂) and brine migration in fractured reservoirs by developing more accurate descriptions of flow interactions between fractures and the rock matrix. The new model was incorporated into a reservoir-scale simulator and sensitivity analyses were performed on the trapping efficiency and storage capacity using the new model. Ultimately, the new model was applied to the In Salah CO₂ storage site in Algeria to simulate CO₂ injection and fracture matrix interaction using historical injection data.

This project is combining laboratory core testing with a novel wireline tool to perform evaluation of in-situ stress and mechanical formation properties at a candidate carbon dioxide (CO2)-storage site in the Newark Basin area. This area was chosen because the possible impacts of seismic hazards and CO2 leakage are particularly important due to a high population density. The approach is expected to be applicable for evaluating geomechanical properties for similar basins, both onshore and offshore.

The scope of the project is to develop a feasibility study to determine the optimal configuration for a coal liquids plant producing jet fuel in compliance with EISA 2007 ?526 GHG requirements. The study focuses on retrofitting the Wabash River Unit 1 - IGCC (Integrated Gasification Combined Cycle). Retrofitting an existing gasification facility reduces technical risk and capital costs leading to a higher probability of implementation and more competitive liquid fuel prices. The study will evaluate options for syngas purification and conversion to jet fuel and options for low carbon power production. The study will also evaluate options for CO2 (carbon dioxide) sequestration either utilizing enhanced oil recovery or alternate methods of sequestration. The study will utilize United States coal as its feedstock and produce fuels that will reduce the United States' dependence on petroleum.

Montana State University will develop engineering strategies for the enhanced production of coal-bed methane (CBM) by stimulating and sustaining the microbial community responsible for methane production in coal beds. The technology will be based on the development of a thorough understanding of the microbiological, physicochemical, and engineering processes involved and necessary to develop a more sustainable CBM) production scheme. To achieve the project goal, Montana State will first determine the chemical and biological parameters limiting methane production from coal. Next, researchers will develop strategies for the optimization of microbially-enhanced coal bed methane (MECBM) technology based on thermodynamic and reactive transport considerations. Finally, scale-up of laboratory microcosms to optimize microbial coal-to-methane production in column flow reactors will be accomplished.

This project evaluated how subsurface strain measurements can be used to improve the assessment of geomechanical properties and advance an understanding of geomechanical processes that may present risks to subsurface carbon dioxide (CO₂) storage systems. Clemson University designed and built instrumentation for measuring the in-situ strain and evaluating the performance characteristics relative to the existing state-of-the-art instrumentation. Data acquired was used to develop analyses for characterizing the strain field associated with injection near the well and in the vicinity of critical features such as contacts and faults.

The project is designed to leverage tools and technologies to improve methods for defining geomechanical risk factors (like geomechanical stress) at carbon dioxide (CO2) storage sites. Project research is utilizing regional geologic data collected from previous and ongoing projects. The methodologies developed under the project may have the potential to enable CO2 storage in many fractured reservoirs through risk reduction, therefore increasing overall CO2 storage capacity by enabling more storage options. In addition, the project has the potential to cut costs by reducing the need for additional expensive testing and logging. The research will benefit both enhanced oil recovery (EOR) and CO2 storage applications.

The proposed work will consist of two parallel, interacting efforts. Pennsylvania State University (PSU) will develop a predictive computational tool by combining first-principles calculations based on density functional theory and computational thermodynamic modeling. Another objective is to improve and make thermodynamic modeling more efficient. The effort at the University of Pittsburgh includes experimental investigations of phase stabilities and oxidation behavior to validate and improve the computational tools. The integrated computational and experimental efforts aim to reduce the time and cost in developing new and tailoring existing materials.

The University of Wyoming Research Corporation dba Western Research institute (WRI), along with LP Amina, Inc., Arizona State University, and New Mexico State University, will develop a high-temperature sorbent-based oxygen production technology. The objectives of the project are to develop and characterize an improved sorbent based on mixed conducting metal-oxide ceramic materials, design and build a bench-scale process to test the robustness of the materials, and evaluate sorbent performance as a function of operational parameters. Arizona State will optimize the properties of new perovskite ceramic sorbent materials; New Mexico State will support the optimization process with bench-scale testing. WRI will perform cyclic pressure swing adsorption experiments leading up to engineering development of the sorbent based oxygen production technology, and LP Amina is the commercial partner.

This project is developing and validating an integrated framework for coupled monitoring and modeling data to analyze the geomechanical impacts caused by carbon dioxide (CO2) injection. The approach combines satellite-acquired surface deformation data, microseismic monitoring data, and numerical modeling; it also leverages monitoring data sets from a large-scale carbon storage project (Big Sky Carbon Sequestration Partnership). The framework is expected to provide a cost-effective approach for monitoring surface deformation coupled to injection and the associated microseismic activity, thus providing a mechanism for evaluating reservoir integrity.

Case Western Reserve University will team with LG Fuel Cell Systems to develop an understanding of the microstructural basis of long-term performance loss in solid oxide fuel cell (SOFC) lanthanum strontium manganite (LSM)-based cathodes and will form strategies for improving long-term performance and microstructural and chemical stability for commercial fuel cell systems. The team will carry out accelerated testing of SOFCs with LSM-based cathodes of selected compositions. After intervals of accelerated testing and control experiments using non-accelerated conditions, the cells will undergo extensive state-of-the-art microstructural and nanochemical characterization to determine the physical and chemical changes in the cells. This program of cell fabrication, accelerated testing, microstructural characterization, and comprehensive analysis will culminate in design rules for LSM-based cathodes, informed by mechanistic understanding of the relationships between microstructural changes during operation and the long-term durability of SOFCs.

The objectives of this research are to (1) develop and integrate modern computational tools and algorithms, i.e., predictive first-principles calculations, computational-thermodynamic modeling, and meso-scale dislocation-dynamics simulations, to design high-temperature alloys for applications in fossil energy power plants; and (2) understand the processing-microstructure-property-performance links underlying the creep behavior of novel ferritic alloys strengthened by hierarchical coherent B2/L21 precipitates.

The Gas Technology Institute (GTI), with support from the University of South Carolina, will develop a proof of concept of an innovative oxygen production technology using a hollow fiber membrane contactor (HFMC) with an oxygen carrier solution as the solvent and air as feed to produce greater than 95 percent purity oxygen. This involves screening of suitable oxygen carriers that are stable and compatible with HFMC materials and possess high oxygen separation rates and capacities, and the identification of ideal HFMC configurations that offer high mass-transfer coefficients (related to oxygen production rate) and operational stability. A techno-economic analysis will be the final task. The Illinois Clean Coal Institute will be providing third-party cost share.

The University of Washington (UW) will develop a novel class of Silicon carbide (SiC)-based ceramic composite materials with tailored compositions for channel applications in magnetohydrodynamic (MHD) generators. The project will investigate the effect of precursor chemistry (specifically C/Si) and processing conditions (e.g. temperature) on the nanodomain structure, resultant stoichiometry, nature of the carbon phase (e.g. graphene sheets, carbon nanoparticles) and the resulting, thermo-mechanical properties at elevated temperatures. Combinatorial Materials Exploration protocol will be used to select the minor constituent X in Si-C-X, and investigate its effect on the electrical properties, including thermionic emissions and arching property for use in MHD generators. Important parameters to be investigated are the domain size, the type and distribution of carbon, the size and volume fraction of crystalline SiC and the constituent X. The interaction of these materials with plasma as a first step toward understanding the plasma induced degradation process will be investigated using a newly developed High Density Plasma-Materials Testing Facility that was previously designed and built on the UW campus.

Michigan State University (MSU) will team with Delphi Automotive Systems (Delphi) to design and test new solid oxide fuel cell (SOFC)-compatible, silver-free brazes to form durable, oxygen- and hydrogen-impermeable protective surface scales. The team will use a combined computational-experimental approach to develop new braze compositions. In addition to instituting a new paradigm for braze development and generating a wealth of important, fundamental material property data, this work will provide new brazes specifically designed to withstand the extremes in temperature, time, atmosphere, and thermal cycling encountered in SOFC operation.

This project is studying the geophysical and mineralogical controls on fracture failure induced either seismically or a seismically, and how this relates to anticipated magnitudes of permeability change and the potential for seal/caprock breaching. The project work provides improved understanding of geomechanical processes and impacts critical to carbon dioxide (CO2) injection operations.

The goal of this project is to evaluate the feasibility of an innovative, integrated, supercritical cogeneration system for cost-effective treatment of produced waters from carbon dioxide (CO2) sequestration, oilfields, and coal-bed methane recovery. Methane or coal is used as energy source to drive the proposed system that generates both electricity and pure water. Project tasks include process simulation, thermodynamic analysis, and techno-economic evaluation of the integrated system; design and assembly of supercritical salt precipitation and membrane distillation systems; development and characterization of advanced carbon membranes for supercritical membrane distillation; and desalination and purification of different produced water samples with salt concentrations of 30,000 ppm (mg/L) to 200,000 ppm.

The goal of the project is to create and validate a robust, multiscale, mechanism-based model that quantitatively predicts long term evolution of microstructure for nickel-based alloys, and the effect on mechanical properties such as creep and rupture strength, including variable cyclic operating conditions. This is a fresh approach to simulating long term material response that embeds established mechanistic understanding within a discrete element method (DEM) model framework to create a predictive system with a sound mechanistic foundation.

The University of Utah will develop new technology to enhance the economic viability of in situ microbial coal-to-methane conversion within otherwise un-mineable fossil fuel resources. The primary objective is to demonstrate a new method for delivering microbes to the reservoir. A new ceramic proppant (used to prop open hydraulic fractures) will be designed specifically to have improved fluid transport properties while simultaneously delivering microbial consortia to coal seams. In tandem, viable nutrients and microbial consortia will be identified. Bench-scale measurements will verify heating value, cost, and production rates.

The project objective is to demonstrate the efficacy of membrane distillation (MD) as a cost-savings technology to treat concentrated brines (such as, but not limited to, produced waters generated from fossil fuel extraction) that have high levels of total dissolved solids (TDS) for beneficial water reuse in power production and other industrial operations as well as agricultural and municipal water uses. In addition, a novel fouling-resistant nanocomposite membrane will be developed to reduce the need for chemicals to address membrane scaling due to the precipitation of divalent ions in high-TDS waters and improve overall MD performance via an electrically conductive membrane distillation process (ECMD). This anti-fouling membrane technology platform is based on incorporating carbon nanotubes (CNTs) into the surface layer of existing, commercially available MD membranes. The CNTs confer electrical conductivity to the membrane surface so that an electrical potential can be applied to remove and prevent membrane scaling and fouling.

Under this project, Washington University will advance the understanding of microstructure and surface chemistry impacts on the flow and mineralization of carbon dioxide (CO2) injected into fractured basalt. The project will integrate geomechanical and geochemical characterization of rock cores to advance the understanding of in-situ characterization of the evolution of fracture structure and carbon trapping mechanisms in basalt.

The University of Kentucky (UK) will develop a catalytic gasification process to drive down the capital costs of coal gasification. Two key innovations will be the focus of the project. The first is the synergistic utilization of chemical looping to provide oxygen to the gasification process, thereby foregoing the necessity of having an air separation unit (ASU). This approach is synergistic because the chemical looping particles will be based on a so-called red mud, comprised mainly of iron oxides that should catalyze the gasification process as well as enhance the water-gas shift (WGS) process required to achieve a high-hydrogen syngas—necessary for generating electric power while capturing carbon dioxide emissions. The second key innovation is a spouted bed reactor configuration. This configuration will be developed by UK to enhance the gasification reaction performance.

GE Power & Water will develop cooled high-temperature ceramic matrix composite (CMC) nozzles (non-rotating airfoil hardware) as an innovative turbomachinery component contributing towards the DOE's goal for advanced gas turbine efficiencies that are greater than 65% in combined cycle applications, including coal based IGCC. This project, by leveraging existing design and analysis knowledge and techniques for CMC materials, will utilize extensive analytical evaluations to develop and refine designs for a CMC nozzle in an industrial gas turbine hot gas path. The Phase I project scope of work will consist of three elements: (1) design and analyze attachment configurations: a bayonet style and a more traditional airfoil with two end-walls, (2) investigate impingement and film cooling, and (3) define sealing approaches, design key sealing features, and analyze sealing effectiveness for the best designs. Limited bench flow testing will be performed to support these efforts. The design, or designs, will be the basis for development and testing in a potential future Phase II. Previous related work was performed under DOE contract FC26-05NT42643.

Acumentrics will team with the National Renewable Energy Laboratory (NREL), under separate field work proposal FWP-HYW1052A, to improve solid oxide fuel cell (SOFC) system reliability. Non-destructive and automatable techniques will be developed for identifying defective SOFC cells prior to stack and system assembly, thereby improving quality control and long-term performance by preventing premature stack failure (see Figure 1). High-speed methods for defect detection and an understanding of the type of defect and its effect on degradation will be established to progress towards commercially viable production rates.

This project goal is to demonstrate how tailoring Hot Isostatic Pressure of Powdered Metal (HIP/PM), coupled with advances in Additive Manufacturing (AM) has specific, measurable benefits for fabricating advanced energy system components. The objectives for the project include: 1) produce fully dense test coupons to determine the requisite material characterization and sintering protocols, 2) produce two HIP cans in A 282 with different wall thicknesses, and 3) analyze valve parts for chemical and material properties.

TDA Research Inc. (TDA), with support from the University of California, Irvine, will develop a new chemical absorbent-based air separation process that can deliver low-cost oxygen to various advanced power generation systems, including oxygen-fired pulverized coal boilers and integrated gasification combined cycle (IGCC) power plants. Specific objectives of the proposed work are to increase the technical maturity and commercial viability of the new oxygen separation technology by (1) demonstrating continuous oxygen generation in a continuous circulating bed system, and (2) carrying out a high-fidelity system design and techno-economic analysis. In two previous DOE projects (FG02-05ER84216 and FG02-07ER84677), TDA demonstrated the efficacy of the new air separation concept integrated with an IGCC plant and an oxy-combustion process.

This project is undertaking a probabilistic risk assessment of pressure-induced fracture dilation, hydraulic fracture, and shear failure during industrial-scale carbon capture and storage (CCS) at the Wallula Basalt Sequestration Pilot Project. Core-flood experiments are being used to determine multi-phase fluid properties of variably saturated rock, and the project team is measuring stress-dependent permeability changes with increasing formation pressure. Monte Carlo numerical simulations are being used to assess the probability of tensile, shear, and breakdown failure within the reservoir rock and overlying formations. The results of the study will be an improved accuracy of existing models to understand impacts of carbon dioxide (CO2) injection on reservoir permeability.

This work proposes to develop novel combustor components that can be used in high temperature energy systems, such as oxy-fuel based magnetohydrodynamic (MHD) systems, which will reduce CO2 emissions and provide a combustor system that can be coupled to achieve high efficiency energy conversion rates. To meet this goal, existing facilities will be modified to accommodate a high temperature and high velocity oxy-fuel flow. Deliverables include the design, fabrication, characterization, testing, and documentation of the combustor system performance for use in future computational and system development and construction.

The objective of this project is to establish the technical and economic feasibility of the multiphase turbo-expander water desalination process with a cost of water treatment at least 20% less than thermal evaporation. The key component of the proposed process is an expander capable of working with three phases of the expanding fluid: air, liquid (concentrated brine), and solid (ice and salt crystals). A specific objective for the expander development is to demonstrate at least 80% brine freeze in the expander.

The scope of this project is to design and evaluate the cost-competitiveness of a commercial-scale integrated facility at a southern Mississippi site. The facility will co-gasify lignite and woody biomass to produce syngas that is converted via Fischer-Tropsch (F-T) synthesis/refining to liquid products. The primary product will be a synthetic jet fuel suitable to substitute for petroleum-derived jet fuel. The plant production capacity will likely be in the range of 5,000 to 15,000 barrels per day of liquid product. A key objective in the design of this lignite/biomass-to-jet (LBJ) plant is lifecycle greenhouse gas (GHG) emissions for the synthetic jet fuel that are less than for petroleum-derived jet fuel. The use of some biomass will help achieve this. Additionally, byproduct CO2 will be captured at the plant, and it will be sold for use in enhanced oil recovery (EOR) to generate revenue.

Based on past experience developing a Transport Membrane Condenser (TMC) for industrial boiler flue gas water and heat recovery, and coal power plant flue gas slip stream tests, Gas Technology Institute will enhance the TMC to greatly increase its water and energy recovery efficiency and lower its capital and operating costs for power plant applications. Phase I objective is modeling, design and fabrication work, including low cost fabrication method evaluation. Phase II objective is to perform testing to verify performance and evaluate its application for power generation industry, carry out plant integration study and cost benefit analysis, and potentials for commercialization.

The goal of this project is to develop the design and manufacturing processes that are required for welded tube membrane panels in power boilers for Advanced Ultra Supercritical (AUSC) steam cycles. This effort is required prior to an AUSC Component Test (AUSC ComTest) facility to demonstrate high temperature, high pressure (up to 760 degrees Celsius (1400 degrees Fahrenheit) and 35MPa (5000psi) steam conditions. Steam cycles operating at AUSC steam conditions can achieve a 10 percent increase in efficiency above current commercially available state-of-the-art USC boiler steam cycles at 29MPa/605 ?C/620 ?C (4200 psi/1121 ?F/1150 ?F). The expected results of the project is a fabricated and heat treated prototype welded tube membrane panel that designed and manufactured for long term (30 years or longer )use at the elevated temperatures and pressures of AUSC steam cycles. The results of this project could also be applied to manufacturing similar assemblies in other advanced fossil energy technologies operating at elevated temperatures and pressures.

The Southwest Research Institute (SwRI), with support from Solar Turbines Inc., will develop a high-temperature heat exchanger design capable of operation in carbon dioxide (CO2) at temperatures up to 1510 degrees Fahrenheit (821 degrees Celsius) and pressure differentials up to 130 pounds per square inch (9 bar). The heat exchanger is proposed for use as a recuperator in an advanced low-pressure oxy-fuel Brayton cycle that is predicted to achieve over 50 percent thermodynamic efficiency, although the heat exchanger could also be used in other high-temperature, low-differential-pressure cycles. The proposed work is based on a proven concept that is actively used for the Mercury 50 gas turbine and will significantly increase the temperature rating of a primary surface heat exchanger used for recuperation.

The goal of this project is to evaluate the potential for low-grade heat to drive water treatment via forward osmosis (FO). The project will evaluate the suitability of using FO to treat wastewater and other impaired water sources for recirculating cooling water makeup water, boiler cycle makeup water, and wet flue gas desulfurization; and to treat ash pond wastewater prior to environmental discharge.

Thar Energy, LLC and Southwest Research Institute propose the design of a compact heat exchanger using microchannel technology for operation at high temperature, up to 700 degrees Celsius, and high pressure differentials, approximately 2,500 psi between streams. This heat exchanger is intended for use in high-efficiency electrical generation systems such as supercritical carbon dioxide (CO2) power cycles. This project will consist of preliminary and detailed design and prototype fabrication and testing. Preliminary design efforts will include a technology gap study, heat exchanger tube material selection, analyses of manufacturing and fabrication techniques, and heat exchanger tube geometry design. Detailed design will consist of computational fluid dynamics (CFD), heat transfer, and structural analysis of the proposed design to examine the flow characteristics and thermal performance. Fabrication will demonstrate compatibility of the selected material and manufacturing technique. Prototype testing will consist of hydrostatic and pressurized flow testing at representative pressure differentials.

The team of Southwest Research Institute (SwRI), GE Global Research, American Air Liquide, Georgia Tech, University of Central Florida, and Spectral Energies will develop a high inlet temperature oxy-combustor suitable for integration into a direct-fired supercritical oxy-combustion power plant for fossil energy applications. Phase I efforts (which included another sub-award, Thar Energy) evaluated a direct-fired oxy-combustion system using system engineering design and thermodynamic analysis to assess plant efficiencies with ancillary loads, verify operating conditions for the supercritical oxy-combustor, and optimize the overall plant configuration. Phase I also included a technical gap analysis of the proposed plant to identify critical component and technology development needs and the initial design of a supercritical oxy-combustor suitable for direct-fired oxy-combustion using natural gas or syngas. The Phase II effort involves the design, hardware fabrication, process controls, and operations required for integrating the 1 MW_e SunShot sCO₂ Test Loop (developed under DE-EE0005804) with a ‘first-of-a-kind’ supercritical oxy-combustor along with consideration of thermal management, water separation, flue gas cleanup, materials, and corrosion. The 1 MWt sCO₂ oxy-combustor will provide a portion of the total SunShot test loop sCO₂ that is circulated.

This project will develop and optimize a water treatment system, herein called COHO (CO2- H2O), that will use low-grade waste heat and carbon dioxide from flue gas at power plants. COHO will have higher water recovery and will be able to treat more problematic water using less energy compared to state-of-the-art technologies. The goals of the project are to first optimize the system process, including; carbon dioxide and water processing as well as the draw chemistry. Porifera will build, operate, and test the system at a power plant, develop technoeconomic model of COHO, and demonstrate the viability.

The University of Pennsylvania, with team members University of South Carolina and Fuel Cell Energy (FCE), will address two critical problems with solid oxide fuel cells (SOFCs)—manufacturability and stability—by developing simple, cost-effective processes for manufacturing nanostructured cathodes and unique methods to stabilize the nanostructured cathodes under typical SOFC operating conditions. Team members will conduct fundamental studies of cathode properties and detailed characterization of their structure. The newly-developed cathodes will then be incorporated into industrial-scale cells and their performance validated.

Aerojet Rocketdyne (AR), and team members RTI International (RTI), Gas Technology Institute (GTI), Coanda, and Nexant, are developing and maturing an advanced pilot-scale gasifier for use in a first-of-a-kind, commercially relevant demonstration plant. AR has successfully designed and operated a compact gasifier at a pilot scale. AR and Coanda are teaming to test quench zone simulations. RTI is furthering existing research into advanced water gas shift catalysts, which will enable and reduce the cost of high-H2 syngas production. GTI will test a range of coals, as well as a coal/natural gas hybrid, in the compact gasifier. Nexant will prepare a techno-economic analysis based on the outcome of these efforts, validating the benefits of the proposed technologies for both integrated gasification combined cycle (IGCC) and coal-to-liquids (CTL) plants.

Brayton Energy goal for this project is to advance the state of development of heat exchanger technology for high-temperature (up to 850 degrees Celsius), high-pressure (up to 25 Megapascal) operating conditions within advanced power generation applications, such as supercritical carbon dioxide (SCO2) power cycles. The work will be based upon Brayton's plate-matrix heat exchanger technology, currently under development. The scope for this project includes manufacturing development, heat exchanger characterization testing, and cost modeling. The flattened-panel heat exchanger cell was conceived and prototyped as part of DOE contract DE-EE0005799.

The goal of this project is to model long-term creep performance for nickel-based superalloy weldments in high temperature power generation systems. The project will use physics-based modeling methodologies and algorithms to predict alloy properties in heterogeneous material structures. The modeling methodology will be demonstrated on a gas turbine combustor liner weldment of Haynes H282 precipitate-strengthened nickel-based superalloy.

The goal of this project is to perform the pre-front end engineering design (Pre-FEED) of a gas fired advanced ultrasupercritical (A-USC) steam superheater capable of operating at 760 degrees Celsius (?C)steam temperature. The superheater would be part of a future A-USC component test program. The pre-front end engineering design package will include data definition, systems evaluation and materials/components selection that would be needed to complete final engineering design of the A-USC steam superheater in an A-USC component test facility. Plans for the steam superheater manufacturing, construction, commissioning, operation and testing will also be developed in this project. The expected results of the project will be the completed pre-front end engineering package for procurement, construction, and installation of an A-USC steam superheater capable of operating at 760 ?C, and as close as possible to the mechanical stress conditions that would be expected in a commercial scale A-USC superheater.

The goal of this project is to develop an oxidation/corrosion model to predict the performance of structural alloys in terms of oxide growth rate and tendency for scale exfoliation, in supercritical CO2 in severe operating environments at high temperatures. This goal will be accomplished by: 1) short-term isothermal lab scale oxidation/corrosion tests in high-pressure (200 atmosphere [atm] or higher) and high-temperature (650-750 degrees Celsius) supercritical CO2; 2) characterization of the oxide scales on the exposed samples, determination of the oxide scale growth and exfoliation kinetics and 3) modeling of the process of oxide growth and exfoliation with and without heat-flux, and application of the model to actual tube geometries. A longer-term exposure on a relevant geometry will also be conducted as a confirmatory test for the developed model. Using the model results, recommendations will be made for structural materials selection for alloys in high temperature supercritical CO2 environments. A validated model to predict oxidation and exfoliation rates of structural alloys in advanced supercritical CO2 (sCO2) power generation cycles will be developed.

Mohawk Innovative Technology will develop a ceramic heat exchanger with high effectiveness and low pressure drop to work as a preheater for solid oxide fuel cell (SOFC) application. The objectives for the project include R&D work to select a design, material, and fabrication method for the heat exchanger followed by component tests under relevant SOFC conditions.

Praxair will focus on developing a techno-economic analysis of an integrated gasification combined cycle (IGCC) power plant with CO2 capture with an integrated oxygen transport membrane (OTM) syngas converter. Other process variables will include using natural gas as a secondary feedstock and evaluating the conversion of coal and natural gas-derived syngas to liquid fuels. The results of this analysis will be incorporated into a scalable panel array module, which will be field tested at the National Carbon Capture Center using syngas from a coal-fed gasifier. This project builds on the success of work undertaken with DOE support to develop basic ceramic materials, single-tube membrane structures, and process integration strategies for oxy-fuel combustion.

The proposed hybrid CTL process integrates a number of emerging technologies anticipated to produce jet fuel that is cost competitive with that from petroleum with an equal or lower carbon footprint. The process technology components selected for the hybrid CTL process include Aerojet Rocketdyne (AR) advanced compact gasifier with dry solids feed pump and natural gas partial oxidation (POX) technologies and RTI warm syngas cleaning (WDP) and novel syngas-to-liquids (STL) technologies. In Phase I, a bench-scale STL reactor system will be used to provide liquid hydrocarbon samples suitable for upgrading to jet fuel. RTI will work with Axens to use the analysis of these samples to evaluate upgrading configurations and optimize the configuration of RTI STL system for producing a jet fuel intermediate. In Phase II, the integrated 1 BPD pilot-scale test will be used to produce approximately 1 barrel of intermediate product from syngas generated from coal, natural gas and combinations of coal and natural gas. The intermediate product from these pilot scale tests will be upgraded by Axens into jet fuel. The preliminary techno-economic analysis completed in Phase I will be updated with the experimental data obtained from the pilot scale testing and upgrading.

Altex and its partners will design, fabricate, test, and assess the performance of a greater than 1 barrel per day process to produce synthetic JP-8 jet fuel. The process combines lower temperature fast pyrolysis and the production of a targeted intermediate that can be converted to a liquid hydrocarbon fuel at a lower cost than gasification/Fischer-Tropsch methods. The system will be tested utilizing low-rank U.S. mined coal (lignite and/or subbituminous) and lignocellulosic biomass in ratios between 51% and 85% coal by higher heating value (HHV). The product will be sent to third parties for testing compliance with key military jet fuel specifications.

The Ohio State University (OSU) will demonstrate the long-term operation of their 250 kilowatt syngas chemical looping (SCL) pilot at the National Carbon Capture Center (NCCC) in Wilsonville, Alabama. The project team consists of OSU, Babcock & Wilcox Power Generation Group, First Energy, and Clear Skies Consulting. The scope of work consists of (1) maintenance, startup and operation of the SCL pilot unit in hydrogen generation mode for chemical production for up to four gasifier test campaigns at the NCCC and (2) completion of a technical and economic evaluation of the technology based on knowledge gained from these campaigns. This evaluation will be used to develop a deployment path for the SCL technology. The construction of SCL pilot unit was completed by OSU under a previous competitively-selected DOE ARPA-E Cooperative Agreement, DE-AR0000017.

United Technologies Research Center will further advance pressure gain combustion (PGC) systems and transition this technology to combined-cycle gas turbines. The objective of the project is to assess the potential benefit of PGC system technology for combined-cycle gas turbines and compare it to the DOE goals. Multiple analyses will be completed in order to accomplish this objective. A system cycle model of the entire combined-cycle turbine system and the modules that model the unique components of the PGC system will be developed and validated against the existing experimental data. The immediate outcome of the program would be a realistic assessment of the potential efficiency improvement of PGC technology on combined-cycle power generation and an accurate assessment of the commercial impact of its adoption. Additionally, the program would document the technical gaps and the required research and development to overcome them.

Altex Technologies Corp. (Altex) and project team partners—Dresser-Rand(D-R), Echogen, and Babcock & Wilcox (B&W)—will develop, design, and build a 500 kilowatt (kW) High Effectiveness Low Cost (HELC) Recuperative Heat Exchanger (RHEX) for supercritical carbon dioxide (SCO2) waste heat power systems. Altex will build and test coupons as well as deliver an available 30 kW HELC in a SCO2 laboratory test system at Echogen. Echogen will test the unit and provide data and feedback to the team. Using the smaller scale (coupon and 30 kW articles) test results and analyses, and B&W inputs on materials selection, Altex will develop and design a 500 kW unit for testing, and use ISO and ASA certified manufacturers to fabricate and bond the unit. After quality checking the integrity of the unit, it will be installed in Echogen's 250 kW demonstrator power system and tested by Echogen under the power system operating conditions of interest. Using the test data and analysis, the performance and economic benefits of HELC will be determined by Altex. Finally, D-R and Altex will develop a transition plan to support the commercialization of HELC RHEX. Altex has developed HELC under previous DOE contract DE-EE0004541.

The project seeks to develop a high-temperature and compact ceramic heat exchanger based on the laminated object manufacturing technique. Ceralink will perform the fabrication of sub-scale and full-scale heat exchanger prototypes and address issues related to sealing of the heat exchanger. United Technologies Research Center (UTRC) will develop heat exchanger models and provide designs for fabrication by Ceralink. UTRC will also perform high temperature tests for heat exchanger prototype validation. The goal is to produce and test a full-scale, high temperature compact ceramic heat exchanger by the end of the project.

The goal of this Southern Illinois University (SIU) project is to maximize methane productivity from bituminous coal through adding a nutrient medium. To achieve this goal, SIU aims to simplify the composition of the nutrient solution used in previous studies (that showed a 50-fold higher methane production compared to that without a nutrient medium); maximize methane yield by investigating individual and interactive effects of different parameters such as coal particle size, temperature, pH, mixing, and addition of surfactants, solvents, and electron donors in microcosm setups; and investigate methane production through biological coal conversion (BCC) in a fed-batch cultivation mode. SIU will then evaluate methane yield in a dynamic bioreactor system where nutrient or other supplements can be added and methane and headspace gas can be withdrawn intermittently. Finally, methane production using established microbial consortia in pressurized reactors will be investigated.

Research conducted under this project aims to develop Alstom limestone-based chemical looping gasification (LCL-G™) concept for conversion of coal to high-hydrogen syngas for power generation and/or liquid fuel production. NewCO2Fuels Ltd. will provide solid oxide electrolysis cell-based hydrogen production expertise, and the Illinois Clean Coal Institute will provide financial support. The LCL-G process will be evaluated and refined using bench-scale testing followed by process validation at Alstom 3-megawatt (thermal power) chemical looping test facility. A techno-economic assessment of the LCL-G technology for power and/or diesel fuel synthesis will be conducted to demonstrate that the system has the potential to meet DOE cost and performance goals.

TDA Research Inc. (TDA) will develop an integrated water-gas shift (WGS) pre-combustion CO2 capture technology to eliminate CO2 emissions from integrated gasification combined cycle (IGCC) power plants and coal-to-liquid plants. The project team includes the Gas Technology Institute (GTI); the University of California, Irvine (UCI); Indigo Power Systems LLC (Indigo); the National Carbon Capture Center (NCCC); Praxair; and CB&I Lummus Technology (CB&I). The team will design a gasification reactor using computational fluid dynamics and kinetic modeling to achieve optimum CO2 removal and hydrogen recovery. TDA will be the lead and perform the system design and sorbent production. TDA will work with GTI in the design and fabrication of a slipstream test unit. UCI and Indigo will conduct the process modeling and design and carry out the system and economic analyses. Praxair will support the field tests at the Praxair Facility in Tonawanda, NY.

Edison Welding Institute will develop a novel process to qualify the additive manufacturing (AM) technique of laser powder bed fusion (L-PBF) for complex gas turbine components made of high temperature nickel-based alloys. The project objectives include evaluating the impact of (1) powder selection method, (2) AM machine process parameters, and (3) heat treat sensitivity on the manufacture of production-scale fuel injector tips.

Aerojet Rocketdyne, Inc. will develop, validate, and integrate a systems model for a rotating detonation combustor into an overall systems model of a power plant and define the path to configurations that exceed 65 percent combined-cycle efficiency. The RDE system presents an opportunity for potential performance improvement because of the similarity of the detonation process to constant volume combustion. This program will begin by developing and validating a system simulation tool for integration into a power plant systems model. Results will be implemented into the power plant systems model to define the path to configurations that exceed 65 percent combined cycle efficiency.

Ceramatec will collaborate with The Colorado School of Mines (CSM) to meet the project objectives. Ceramatec will lead the project and will be responsible for fabricating and testing heat exchanger plates and stacks. CSM will derive heat exchanger plate specifications from system requirements using numerical power systems modeling approaches, such as ASPEN. Subsequently, CSM will work with Ceramatec to design the microchannel architecture for a heat exchanger plate that will be the basic repeat unit of heat exchanger stacks. CSM will perform 3-D, computational fluid dynamics, using numerical modelling tools such as FLUENT. Ceramatec will fabricate heat exchanger plates using its unique microchannel manufacturing capabilities and test the behavior of the plates in laboratory apparatus. Test results will be used as feedback to iterative design modifications. These activities will serve to define a heat exchanger plate design for stack testing. Ceramatec will fabricate heat exchanger plates and assemble them into stacks capable of 1-5 kWth thermal duty. Ceramatec will integrate the stacks with appropriate manifolds and thermal systems for subsequent testing at elevated temperature.

Southern Research Institute will conduct a research and development project to provide innovative improvements to indirect coal liquefaction for conversion of coal or coal/biomass mixtures to jet fuel with high productivity and selectivity. This project proposes the production of a hydrocarbon product from a coal/biomass blend. The hydrocarbon product will be directly blended with petroleum-based jet fuel at approximately 50% by volume with the resulting mixture meeting JP-8 specifications. The project focus is to reduce the cost, increase process efficiency and improve the life-cycle for coal-to-liquids (CTL) production of jet fuel through process intensification design upgrades for the reactor, catalyst and catalyst bed configuration.

Siemens Energy Inc. will develop a ceramic matrix composite (CMC)-based design for Siemens Advanced Transition in support of 65 percent efficient gas turbines. The primary deliverable is a design concept ready for fabrication and test in a follow-on (Phase 2) project. Siemens patented Hybrid Oxide CMC system will be the basis for the design of this part.

Ceramatec intends to demonstrate the production of jet fuel from a coal and glycerol or other biomass. The project will integrate several unique technologies to produce a product that may be directly blended with jet fuel from petroleum based sources. The cost is anticipated to be competitive with jet fuel from petroleum, and generate approximately 30 percent less Greenhouse Gas (GHG) emissions compared to conventional petroleum-based jet fuel. Process modeling will be performed to determine the mix of coal and glycerol or other biomass to achieve the target emission reduction and cost. Successful completion of this project will provide the data required for design of a commercial facility capable of providing jet fuel meeting specification and establishing the ability to produce jet fuel from coal with reduced GHG emissions.

This project focused on investigating a direct coal/biomass to liquids (CBTL) process for producing jet fuel that uses novel biomass-derived solvents with excellent hydrogen-donor capability, eliminates molecular hydrogen required for producing syncrude, and operates under milder conditions (approx. 500 vs. 2,500 psi). All major process steps were explored and refined at bench-scale under continuous operating conditions, including (a) biomass conversion to high hydrogen-donor solvents; (b) coal dissolution in biomass-derived solvents to produce syncrude; and (c) two-stage catalytic hydrogenation/ hydrotreating of syncrude to jet fuel and other distillates. The process was scaled to continuous, pre-pilot scale. Project development efforts—utilizing domestic coal as 55-percent of the input feedstock on a BTU basis (higher heating value) and 45-percent biomass via the direct CBTL process—are expected to advance development of high-hydrogen donor bio-oil solvents and two-stage catalytic syncrude hydrogenation/hydrotreating technologies.

8 Rivers Capital, along with Toshiba Corporation, will develop an innovative, first-of-its-kind, oxy-syngas combustor operating at high-pressure with supercritical carbon dioxide (SCO2) diluent and cooling. This project will advance coal syngas combustion in the environments required by these systems through developing a conceptual design of a syngas-fueled combustor-turbine block for 300MWe, high-pressure, oxy-fuel, SCO2 power system. 8 Rivers will also produce a preliminary detailed design of a 5MWth test combustor and the design of a test program and rig to demonstrate the feasibility of the combustion environment.

Aerojet Rocketdyne (AR) along with Duke Energy, Alstom Power, Electric Power Research, and Oak Ridge National Laboratory (ORNL) are developing more innovatively mature turbomachinery components for indirectly and directly heated supercritical CO2 (SCO2) power generation cycles. The project team will perform systems analyses for both directly and indirectly heated cycles; perform turbomachinery layout studies; and perform a technology gap analysis to assess where future investments and testing are needed. AR and ORNL will also perform long duration high-temperature, high-pressure exposure tests on a variety of materials in SCO2 to determine materials compatibility and inform future turbomachinery designs.

The project will demonstrate the feasibility of a novel and innovative approach for managing and maximizing reuse of waters produced for reservoir pressure and plume management during CO2 injection. This approach aims to be environmentally sustainable. The produced brines will undergo pre-treatment and/or pre-concentration (if total dissolved solids is < 50,000 mg/L) prior to evaporation. Following evaporation, the very concentrated waste brine and solids will undergo solidification/stabilization to form an easily manageable solid that can be landfilled. Moisture in the flue gases from the evaporation process will be condensed using supercritical CO2 as the working fluid to recover water for reuse.

The objective of this project is to conduct an engineering study as a prelude to a field demonstration of how low-grade waste heat can be used to reduce water usage rates and improve system efficiency in a coal-fired power plant. A commercial system combining low-grade heat-recovery technologies and end uses to cost-effectively improve efficiency and reduce water consumption is yet to be developed. The project team will identify combinations of heat-recovery/use technologies that match up well for heat and temperature profiles, enabling identification of near-term opportunities for utilities to use waste heat; quantify the value of potential improvements in heat-recovery technologies with respect to the cost of the technology, potential increased benefits by widening availability of heat-uses that can be coupled with them, and potential water savings in terms of amount of water per unit of power produced; and recommend a combined process to be field tested at a Southern Company plant.

The goal of this research is to identify and quantify the nonconventional carbon dioxide (CO2) enhanced oil recovery (EOR) target opportunities within the thick Cypress Sandstone in the Illinois basin. This will be accomplished by completing detailed reservoir characterization and modeling, developing CO2 injection scenarios to maximize storage efficiency, and determining economics for increasing oil recovery while storing CO2.

The objective of the project was to develop and apply a universal methodology for estimating the carbon balance of a carbon dioxide (CO₂) enhanced oil recovery (CO₂-EOR) operation and to make the determination of whether the operation can attain Net Carbon Negative Oil (NCNO) classification. The project team identified and framed critical carbon balance components for the accurate mass accounting of a CO₂-EOR operation and developed strategies that are conducive to achieving an NCNO classification. In addition, the researchers considered energy-intensive components of the operation not typically included in carbon life cycle analyses and similar studies, such as compression and fluid handling. The team selected the Cranfield site in Mississippi (an active CO₂-EOR field) as the ideal case study field.

The project team identified and evaluated residual oil zones (ROZs) in the Williston and Powder River Basins through comprehensive reservoir basin evolution modeling, simulation, temperature and saturation logging, and fairway mapping. The presence, extent, and oil saturation of ROZs in the Williston and Powder River Basins was identified and the oil in place (OIP) and carbon dioxide (CO2) storage potential was determined. The research identified ROZs in both basins that could promote further domestic oil production and encourage further CO2 capture for utilization in recovering oil from these and other sedimentary basins.

The project is developing improved tools and techniques to assess and validate fluid flow in tight, fractured reservoirs resulting in an ability to better characterize and determine the storage capacity for CO2 and enhanced oil recovery (EOR) potential of tight oil formations. Specifically, the project is developing methods to better characterize fractures and pores at the macro-, micro-, and nanoscale levels, identifying potential correlations between fracture characteristics and other rock properties of tight oil formations, correlating core characterization data with well log data to better calibrate geocellular models, and evaluating CO2 permeation and oil extraction rates and mechanisms.

The project will build and demonstrate high performance Micro-Electro-Mechanical Systems (MEMS) accelerometer technology for improved seismic imaging. If successful, this new MEMS technology will significantly reduce deployment costs for seismic instrumentation and could make a fully "instrumented" oil field /gas reservoir a reality.

The Institute for Clean and Secure Energy is conducting research to improve industry's ability to utilize the vast energy stored in domestic oil shale and oil sands resources in a manner that will minimize environmental impact and effectively capture the combustion CO2 from production, upgrading, and refining of the produced liquid fuel. The objective of this research is to perform engineering, scientific, and legal research directed toward the development of oil shale and oil sands resources in Utah. This validation research brings together multi-scale experimental measurements--from molecular scale through pore scale and, ultimately, reservoir or basin scale computer simulations--to enhance our understanding of the geology and in situ processing parameters controlling efficient production of oil shale and oil sands resources. Knowledge gained from this research will apply to most, if not all, industry processes and, in particular, those processes that utilize in situ methods for resource recovery.

In this Marcellus Shale project, optimal flowback water treatment processes will be identified, and acid mine drainage water will be examined as a potential supplement to water used for hydrofracturing. Novel viscosity modifiers that are stable under high salinities will also be developed. Successful completion of this project will reduce the amount of freshwater needed and minimize the disposal costs.

PTTC will transfer information and R&D results from both Department of Energy (DOE)-supported and industry research to a broad oil and natural gas stakeholder audience, including independent producers, academia, technology developers, the service sector, and majors. The technology transfer will primarily be in the form of workshops, newsletters, e-mail alerts, and tech centers on the internet.

The goal of this project is to develop a new CO2 injection enhanced oil recovery (CO2 EOR) process using engineered nanoparticles with optimized surface coatings that has better volumetric sweep efficiency and a wider application range than conventional CO2 EOR processes. The objectives are to (1) identify the characteristics of the optimal nanoparticles that generate extremely stable CO2 foams in situ in reservoir regions without oil; (2) develop a novel method of mobility control using "self-guiding" foams with smart nanoparticles; and (3) extend the applicability of the new method to reservoirs having a wide range of salinity, temperatures, and heterogeneity.

The goal of this project is to develop mobility control agents using surfactants injected with carbon dioxide (CO2) rather than with water for CO2 enhanced oil recovery (EOR) in heterogeneous carbonate and sandstone reservoirs. Objectives are to (1) reduce CO2 mobility in CO2 swept portions of the reservoir—but not at the light-hydrocarbon enriched CO2 displacement front; (2) reduce mobility more in higher permeability than in lower permeability intervals; (3) improve distribution of injected fluids in natural fracture networks; (4) reduce the amount of surfactant required to achieve successful mobility control; and (5) achieve displacement efficiency well below the MMP by using surfactants with ultra-low water/oil interfacial tension . These attributes will divert CO2 from swept regions to regions with unswept oil.

The goal of this project is to develop and evaluate, through coreflood tests at reservoir conditions, a nanoparticle-stabilized carbon dioxide (CO2) foam system that can improve CO2 sweep efficiency in CO2 enhanced oil recovery (EOR) and minimize particle retention in the reservoir.

The University of Illinois is developing a State-of-the-Art 3-D visualization and analysis software package targeted to improve development of oil and gas resources. Reservoir Visualization and Analysis (RVA) will display data, models, and reservoir simulation results. It will have the ability to allow users to visualize and query data from geologic models and reservoir simulations. This will improve exploration and development cycle time and also improve the technical quality of interpretations and development decisions. Key capabilities of RVA will include simultaneous viewing and analysis of multiple reservoir fluids and data mining of combined geologic models and reservoir simulation results. The overall technical objectives to be accomplished during the project's three phases are: (Phase 1) visualization code development, a detailed design plan of software capabilities, and complete and publicly release RVA software Beta 1.0, (Phase 2) complete and publicly release RVA software beta 2.0, and (Phase 3) complete and publicly release RVA software version 1.0, and the final open source release of 2.0. Multiple RVA software workshops for technology transfer of the final open source version of the RVA software will be conducted.

The University of Texas of the Permian Basin plans to optimize technical and economic performance of a residual oil zone (ROZ) carbon dioxide (CO2) flood and transfer the knowledge to small producers. The objectives are to (1) characterize the main pay zone (MPZ) and ROZ within the ROZ pilot area; (2) conduct laboratory analyses and reservoir simulation to evaluate the performance of the ROZ pilot flood; and (3) provide recommendations for an optimum field-wide expansion of the CO2 flood in the ROZ and MPZ at the Goldsmith Field. Major project activities include (1) developing a detailed characterization of the MPZ and ROZs from a 1150 feet of core to be provided by the field operator at the Goldsmith-Landreth San Andres Unit, Ector County, TX; (2) examining formation and fluid geochemical analyses to develop an understanding of the differences between the ROZ and MPZ; (3) describing depositional and diagenetic processes in each zone to assist project planning, flood optimization, and design; (4) performing simulations using laboratory and core descriptions; (5) designing logging profile techniques to optimize conformance in injection and production wells, and executing them with new and innovative techniques while using capillary tubes in production wells for fluid lift enhancement; (6) conducting comparative analysis of the dedicated ROZ and the co-mingled MPZ ROZ project; and (7) entering analytical results into an analog SADR/MPZ/CO2 floods database.

Ohio State University (Ohio State) plans to significantly increase the understanding of the occurrence, volume, and fine scale distribution of natural gas hydrate in the northern Gulf of Mexico (GOM) using petroleum industry and Gulf of Mexico Gas Hydrate Joint Industry Project (JIP) well logs. To accomplish this, over 1700 industry well logs from wells that penetrate the gas hydrate stability zone will be analyzed for occurrence of natural gas hydrate in both sand and clay reservoirs. The industry well log analysis will be coupled with analysis and high-resolution modeling of the sand and fracture gas hydrate reservoirs using well logs collected during the JIPLeg 2. Finally, Ohio State will use modeling results from the JIP Leg 2 wells and the industry analysis as inputs to a Monte Carlo simulation to formulate an estimate of the volume of natural gas hydrates in sand reservoirs and all sediment types in the GOM.

Southern Methodist University (SMU) plans to assess the contemporary state of the upper feather edge of deepwater methane hydrate stability on the U.S. continental slope to determine if it is in equilibrium with present-day climate conditions. During phase one of the project, SMU will conduct numerical modeling with upgraded, computer systems running Matlab and seismic processing codes. In Phase 2 SMU will perform an assessment to locate and commit to a vessel for use in completing the Phase 2 field-based component of the project. Phase 2 activities will also include cruise preparation, including site/transect selection and completion of field-based activities to acquire piston cores, heat flow thermal data, and water column data from the U.S. continental slope. During Phase 3, SMU will conduct extensive laboratory-based analyses of sediment samples collected from the Phase 2 cruise for microbiological, geochemical, and biogeochemical studies as well as conduct cruise preparation and completion of a second field-based cruise. In addition, during Phase 3 enhancements will be made to the numerical model using new data from the cruise to inform updates to the Phase 1 results. Digital data sets acquired on the cruise will be processed, and the data will be prepared for release.

The goal of this project is to apply a multicomponent, multi-dimensional reactive transport simulation code to constrain modern day methane fluxes and to reconstruct past episodes of methane flux that can be correlated with environmental changes. The importance of understanding the role that gas hydrates play in the global carbon cycle and their potential as a future energy resource has long been recognized and are key components of the Methane Hydrate R&D Program. Fundamental questions remain however, as to the residence time of gas hydrates near the seafloor and deeper within the sediment column, the sources and pathways of methane transport, nature and driving mechanisms for flow, and changes in these variables through time. In order to better understand these fundamental dynamics of methane in present and past environments, Oregon State University will model the complex nature of these interactions by adapting a comprehensive kinetic transport- reaction model, based on the CrunchFlow code (Steefal, 2009) to simulate the processes occurring in the sediment column (diagenesis, sediment burial, fluid advection, and multicomponent diffusion) and to estimate net seafloor fluxes of solutes.

Trustees of The Colorado School of Mines plans to relate seismic and acoustic velocities and attenuations to hydrate saturation and texture in order to calibrate geophysical techniques for hydrate exploration, evaluation, and production monitoring. To accomplish this, seismic velocity and attenuation measurements will be conducted in the seismic and borehole sonic frequency band. Other measurements will be made at the same time, such as electric resistivity and micro CT imaging to more thoroughly characterize the saturated samples. A database of properties and petrographic textures will be developed. Related measurements will be made on carbon dioxide (CO2) hydrates to help ascertain if remote methods can monitor the CO2-CH4 exchange reaction. Modeling efforts will parallel the physical measurement component to describe the impact of hydrates on rock physics properties and serve as a predictive tool for use on in situ data. This modeling will start with estimating the tetrahydrofuran, CH4, and CO2 hydrate properties themselves. Models of hydrate-rock properties will be tested, modified, or further developed. Both, the physical data and model results will be compared with actual in situ measurements of hydrate-bearing zones. The in situ data will primarily be in the form of well logs. Attenuation will be included in various combinations of measurements to improve our hydrate predictive capabilities.

The Scripps Institution of Oceanography, University of California plans to develop and test a towed electromagnetic source and receiver system that is suitable for deployment off small coastal vessels and mapping a near-surface electrical structure in shallow water. During the project, the system will be used to collect data over permafrost in the shallow water of the U.S. Beaufort Inner Shelf at locations coincident with seismic lines collected by the U.S. Geological Survey. The electromagnetic data will be used to identify the geometry, extent, and physical properties of permafrost and any associated gas hydrate, using interpretation guided by, and jointly with, seismic data. The data will provide a baseline for future studies of the effects of any climate-driven dissociation of permafrost and hydrate. Results will be used to expand geological and geographical applications of marine electromagnetic methods, and provide a complementary geophysical tool.

The University of Pittsburgh plans to test the effectiveness of various carbon dioxide (CO2) thickener compounds that can induce very large changes in CO2 viscosity at typical injection and reservoir conditions associated with Carbon Dioxide Enhanced Oil Recovery (CO2-EOR). Commitment letters from CO2-EOR operators will be obtained in phase 1 of the project to provide oil, brine, and core field samples and information on field operating conditions for active or planned CO2-EOR floods. Also, laboratory testing plans will be developed during phase 1. In phase 2, coreflood experiments will be performed on sandstone and carbonate cores received from CO2-EOR operators in Phase 1, and performance of compounds that demonstrate ability to both dissolve into and thicken CO2 in order to reduce CO2 mobility and increase oil recovery over a wide range of operational and field conditions will be assessed.

Georgia Tech Research Corporation plans to improve understanding of hydrate bearing, fine-grained sediments by investigating their potential for hydrate-based gas production. To achieve this, laboratory and modeling efforts will be conducted to: assess hydrate formation in fine grained sediment systems and the ensuing morphology, develop techniques to emulate natural hydrate bearing formations, develop analytical tools to predict physical properties, evaluate engineering and geological implications, and investigate the potential for production of gas from these systems.

Fugro GeoConsulting Inc. will lead a team of specialists with specific expertise in all aspects of planning and performance of offshore methane hydrate pressure coring programs, core analysis/testing, and field program reporting to investigate and develop scientific, operational, and logistical plans for a methane hydrate-focused marine pressure coring program. The project is being undertaken as an office desktop planning exercise and will include definition of considerations for scope of work, technical specifications, schedule, and budget. The overall focus of this project is to help enable the future collection of methane hydrate pressure cores, which will add to the body of scientific knowledge of the characteristics of in situ methane hydrate occurrences and contribute to scientific and engineering efforts to assess potential exploitation of methane hydrates as an energy resource.

Fugro GeoConsulting Inc. plans to develop analytical techniques capable of quantitatively evaluating the nature of methane hydrate reservoir systems through modeling of their acoustic response. Techniques that integrate rock physics theory, amplitude analysis, and spectral decomposition will be used. Fugro will develop, test, and verify analytical techniques in which rock physics theory is used to model acoustic (seismic) responses of gas hydrate reservoir systems. The expected outcome of the research effort will be an enhanced ability to quantitatively evaluate and prioritize potential gas hydrate accumulations that may be selected as exploration drilling targets based on 3-D seismic data.

The overall goal of the project is to provide reservoir-specific geological and engineering analyses and methods for the efficient and environmentally safe exploration and production of emerging Green River Formation (GRF) tight oil plays in the Uinta Basin, and an established, yet understudied, Cane Creek shale (and possibly other shale units) of the Paradox Formation in the Paradox Basin. Specifically, the Utah Geological Survey will (1) characterize geologic, geochemical, and geomechanical rock properties of target zones in the two designated basins by compiling data and by analyzing available cores, cuttings, and well logs; (2) describe outcrop reservoir analogs of GRF plays (Cane Creek shale is not exposed) and compare them to subsurface data; (3) map major regional trends for targeted intervals and identify "sweet spots" that have the greatest oil potential; (4) reduce exploration costs and drilling risks, especially in environmentally sensitive areas; (5) improve drilling and fracturing effectiveness by determining optimal well completion design; and (6) reduce field development costs, maximize oil recovery, and increase reserves.

The University of Texas at Austin plans to develop a new generation hydraulic fracturing model that will, for the first time, provide an operator the ability to model the simultaneous propagation of non-planar hydraulic fractures from multiple perforation clusters; thereby, creating a realistic picture of the stimulated rock volume (SRV) around horizontal wells. The goal of the project is to improve the capability to simulate the performance of different fracturing fluids and fracture designs to maximize the effectiveness of the SRV and thereby increase well productivity and Estimated Ultimate Recovery and reduce the overall cost of completing horizontal wells. During the three phase project, a new generation code for hydraulic fracturing will be developed, the new code will be applied to a sample field fracture design, and the simulations will be compared with measured field data.

The overall objective of this project is for Oklahoma State University (OSU) to identify and understand structural and stratigraphic controls on hydrate accumulation and distribution in the Gulf of Mexico leased blocks WR313 (WR: Walker Ridge) and GC955 (GC: Green Canyon) using seismic and well data. The effort is to be completed in three phases. The first phase of the project consists of creating a large-sale (resolution in the order of Fresnel zone) P-wave velocity model using travel-time inversion and a corresponding depth image using pre-stack depth migration, During the second phase of the project OSU will jointly interpret the pre-stack depth migrated images and the full-waveform compressional wave velocity (VP) models that will be obtained in Phase 1 and Phase 2. The final phase of the project is to create a hydrate distribution map using the P-wave velocity and attenuation model created in Phase II and a standard rock physics modeling method and to jointly interpret all available datasets to determine the structural and stratigraphic controls on hydrate occurrence and distribution in GC955 and WR313.

Arizona State University intends to verify and validate the use of capillary pressure functions and relative permeability equations embedded into hydrate numerical simulators. Project objectives include (1) generating pore network images using discrete element modeling based on the grain size distribution of in-situ hydrate bearing sediments; (2) developing a new algorithm to simulate hydrate dissociation and gas expansion and calculate the relative water and gas permeability; and (3) running several simulations to provide verified fitting parameters for the capillary pressure function and the relative permeability equation, and possibly modify or generate those equations. The research will start with compiling the information of in-situ hydrate-bearing sediments including grain size distribution, effective stress, porosity, and consolidation behavior. The gathered information will then be used to generate a sediment packing of a hydrate-bearing reservoir by discrete element modeling (e.g., PFC 3D). A pore network model extracted from the generated sediment packing will represent the pore space of in-situ hydrate-bearing sediments. A numerical algorithm will simulate hydrate dissociation and gas expansion resulting in characteristic curves and relative gas and water permeabilities. The effects of hydrate habit, hydrate saturation, and gas viscosity on the characteristic curve and relative permeability will be investigated through pore-network model simulations.

The objective of the proposed project is to investigate hydrates system dynamics beneath seafloor mounds, a structurally focused example of hydrate occurrence at the landward extreme of their stability field, in the northern Gulf of Mexico.

The overall objective is to provide the gas hydrate community with a proven geologically well-preserved proxy for paleo-SMT reconstructions, and thus allow the use of the magnetic susceptibility paleo-record to assess the natural variability in methane and sulfate fluxes in marine gas hydrate bearing regions. To achieve this goal, this project aims to: (1) reconstruct the paleo-positions of the Sulfate-Methane Transition (SMT) using the magnetic susceptibility and grain size proxy approach in gas hydrate bearing sediment cores collected on the Cascadia continental margin during ODP Leg 204 and IODP Exp. 311; and (2) utilize the gas hydrate systems specific CrunchFlow reactive transport modules to ultimately model the required methane and sulfate fluxes that best explain the paleo positions of the SMT at sites on both the northern and central Cascadia margin. Successful completion of this project will provide the gas hydrate community with a proven geologically well-preserved proxy for paleo-SMT reconstructions, and thus allow us to use this paleo record to assess the natural variability in methane and sulfate fluxes in marine gas hydrate bearing regions. In addition, by establishing this proxy on the well studied Cascadia margin we establish this approach and can then plan to investigate the landward limit of gas hydrate stability, the region most susceptible to environmental change, near Hydrate Ridge.

The University of Texas at Austin plans to predict, given characteristic climate-induced temperature change scenarios, the conditions under which gas will be expelled from existing gas hydrate accumulations into the shallow ocean or directly to the atmosphere. The fraction of accumulated gas that escapes and the rate of escape will be quantified. The predictions will be applicable in Arctic regions and in gas hydrate systems at the up dip limit of the stability zone on continental margins. The behavior will be explored in response to two warming scenarios: longer term change due to sea level rise (e.g. 20 thousand years) and shorter term due to atmospheric warming by anthropogenic forcing (decadal time scale). During the first budget period, project objectives are to review and categorize the stability state of existing well-studied hydrate reservoirs, develop conceptual and numerical models of the melting process, and design and conduct laboratory experiments that dissociate methane hydrate in a model sediment column by systematically controlling the temperature profile along the column. Another objective will be to validate the models against laboratory experiments. In the second budget period, the objectives are to develop a gas flow into sediments model in which hydrate is thermodynamically stable and conduct laboratory experiments to validate the model. The developed models will be used to quantify the rate and volume of gas that escapes from dissociating hydrate accumulations. In addition, specific scaled simulations characteristic of Arctic regions and regions near the stability limit at continental margins will be performed.

The project goal is to develop a coupled numerical model that addresses complex thermo-hydro-chemo-mechanical coupled phenomena in hydrate-bearing sediments. Specially, Texas Engineering Experiment Station (TEES) will incorporate sound and proven relationships while satisfying fundamental conservation principles to develop a new model that will be applied to increase the behavior knowledge base of hydrate-bearing systems. The project will undertake an in-depth review of hydrate-bearing sediment properties and use the findings to update numerical models capable of simulating the complex behaviors of these sediments. Updated models will be corroborated using close form analytical solutions and then compared to available data from past hydrate production-related field experiments. Optimized approaches for potential marine and permafrost field-production studies will be developed.

The University of Washington (UW) is conducting a systematic inventory of methane emissions along a climate-sensitive margin corridor and determine methane sources (microbial, thermogenic, gas hydrate dissociation), sinks, and fluxes within the sediment and water column to understand the effect of contemporary bottom water warming on the upper limit of the gas hydrate stability zone along the Washington margin. In the first phase of this project, UW conducted pre-expedition analysis and modeling using archived and recent geophysical and oceanographic data. In Phase 2, UW completed a ten-day field program on the R/V Thompson to collect geochemical and geophysical data. In the final phase of the project, UW will complete post-expedition geochemical and geophysical analyses, data synthesis and interpretation, and reporting and publication.

The Massachusetts Institute of Technology (MIT) and the United States Geological Survey will use numerical models and laboratory experiments (including creation of a bubble capture device and a quasi-2D Hele-Shaw cell) to determine how long methane plumes survive in the water column. MIT will also analyze bubble plume hydroacoustic data over the US Atlantic Margin gas hydrates province.

Georgia Tech Research Corporation plans to conduct a review of hydrate-bearing sediment properties and the inherent effects of in situ sampling to design, develop, and field test a new borehole tool that can be used to comprehensively characterize hydrate-bearing sediment in situ. To achieve this, the project will review and update a database of hydrate-bearing sediment properties at Georgia Tech in order to develop robust correlations with index parameters. The resulting information will be incorporated into a tool for optimal field characterization. The tool design will recognize past developments, build on past characterization experience, and benefit from inspiring examples from nature and other fields. In Phase 2, the tool's electronics and instrumentation will be designed, a full-scale prototype will be constructed, and laboratory testing on hydrate sediment analogs will be initiated. Finally, in Phase 3 the borehole tool will, in collaboration with industry, be deployed in the field to characterize both hydrate-bearing and hydrate-free sediments.

Ground Metrics intends to quantify how well in-situ bulk electrical resistivity measurements can be related to the changes in rock properties and fluid propagation that occur as a result of hydraulic fracturing using a new depth to surface electromagnetic (DSEM) imaging method. During Phase 1, they plan to input new rock fracture parameter estimates into mathematical models and project the electromagnetic signal of a fracture; conduct co-located DSEM and passive seismic surveys during a commercial hydrofracturing project to acquire simultaneous data; and utilize conventional hypocenter and more advanced microseismic seismic data processing to calibrate and assess the DSEM-based 3-D resistivity image. Under Phase 2, the intent is to address key scientific and engineering questions related to hydrofracturing by projecting the benefit of DSEM alone, when used in conjunction with conventional microseismic measurements, and design and estimate the cost of generic surveys to conduct new surveys in real-time.

The University of Texas at Austin plans to develop nanoparticle-stabilized CO2-in-water (C/W), N2-in-water (N/W) and N2-in-liquid hydrocarbon (N/LHC) foams for hydraulic fracturing applications. The overall technical objectives to be accomplished during the three phases of the project are: (i) to demonstrate foam stability and viscosity at elevated pressures relevant to hydraulic fracturing, (ii) to demonstrate triggered destabilization tuned by nanoparticle concentration, (iii) to demonstrate the critical shear rate for foam generation at conditions relevant to flowback and, (iv) to demonstrate the capability to stabilize gas/liquid hydrocarbon foam.

The project goal is to investigate methane emitted from dissociating marine hydrates. The University of Oregon will develop models to investigate the influence of sediment properties on the development and dissociation of hydrate anomalies in response to environmental changes and gas supply. Environmental change can cause the evolution of slope strength heterogeneities, such as those associated with the presence of hydrate anomalies. Using numerical modeling, researchers will examine how flow and matrix instabilities can lead to the development of gas-escape features in marine sediments.

Carnegie Mellon University plans to monitor the emissions of methane and other volatile organic compounds (VOCs) from shale gas operations in order to determine direct emission rates and improve the overall understanding of the air quality impacts of shale gas development. The analyses of methane, VOCs, and other air toxics will improve the characterization of air emissions across the spectrum of technologies and processes used in the Marcellus Shale region. Measurements will be conducted at the process level, and at individual sites of differing ages using different control technologies. Measurements will also be conducted to quantify methane emission rates from non-shale gas sources in the Marcellus area. Project results will help determine how fugitive emissions vary based on different technologies and if emissions vary with the age of the facility.

The overall objective of this project is to constrain the biogeochemical response to environmental change of the gas hydrate system on the western Svalbard (Spitsbergen) continental margin (off the coast of Norway) by characterizing gas hydrate abundance and distribution, and the effect of environmental changes on gas hydrate stability. Specifically, Oregon State University will explore the role of biogeochemical processes in the region via pore water and sediment geochemical analysis, microbiological analysis, and kinetic modeling. Locations sampled will provide key datasets for examining sediment temperature fluctuations driven by thermal changes in the overlying water column and by hydrothermal circulation in the sediments.

Pennsylvania State University (PSU) plans to quantify fugitive and total emissions of methane from the Marcellus Shale gas production region of north central Pennsylvania. In phase I of the project, PSU will construct an "inventory" estimate of emissions from regional sources which will be compared with results from an automobile-based sampling of atmospheric methane emissions. In phase 2, PSU will develop regional methane emissions estimates based on aircraft, automobile, and tower-based observations, and construct independent estimates of the relative contributions of regional sources.

West Virginia University Research Corporation intends to evaluate the environmental impacts associated with diesel engine emissions from unconventional natural gas resources development operations and the potential of economics and emission reductions associated with converting them to dual fuel diesel and natural gas engines. The overall technical activity can be broken down into four objectives to (1) create a diesel engine inventory, their use, and emissions incurred during unconventional well development; (2) analyze the benefits of operating these, or similar engines, on dual fuel or dedicated natural gas to determine regulated and non-regulated emissions and fuel cost reductions; (3) to examine and determine operating and fugitive methane (CH4) emissions effects based on the operation of current technologies on a variety of natural gas compositions; and (4) to examine new catalyst formulations that can be used in conjunction with these developing technologies to minimize new fugitive CH4 emission sources associated with unconventional well development.

Oceanit Laboratories, Inc. plans to demonstrate how real-time sensing of Nanite can improve long-term wellbore integrity and zonal isolation. Nanite is a cementitious material containing a proprietary formulation of functionalized nanomaterial additive to transform conventional cement into a smart material responsive to pressure (or stress), temperature, and any intrinsic changes in composition. Nanite's electrical, radiometric, and acoustic properties; improved chemical and physical properties; and durability have the potential to ensure long-term wellbore integrity and zonal isolation. During Phase 1 Nanite's oil and gas cementing applicability will be verified via baseline monitoring, cement curing process calibration, and electrical resistivity and acoustic property characterization. Methods and technologies to measure and characterize the Nanite material sensing capability will also be developed. Nanite formulation modifications will be made for improved, reliable detection of top-of-cement and cement sheath around the casing using conventional and non-conventional detecting technique. Researchers will complete a comprehensive characterization of Nanite slurries using API recommended practices for cementing slurries.

This project's focus is to evaluate an Acid Mine Drainage (AMD) water treatment technology (HydroFlex) for the purpose of providing treated AMD as an alternative source of water for hydraulic fracturing operations. The HydroFlex technology allows the conversion of a previous environmental liability into an asset while reducing stress on potable water sources. The technology achieves greater than 95 percent water recovery, while removing sulfate to concentrations below 100 milligrams per Liter (mg/L) and common metals (e.g., iron and aluminum) below 1 mg/L. Battelle Memorial Institute conducted a series of laboratory tests to support AMD water treatment technology optimization for use in hydraulic fracturing. The laboratory test results were used to determine site-specific water quality and potential reuse of any byproducts (e.g., purified water, metals, sulfates). A field demonstration site at Sarver, PA was selected and a demonstration system was installed. The first test campaign was completed in late August, 2015; depending on results, a second campaign may be conducted.

University of Texas at Austin (UTA) plans to evaluate, by means of numerical simulation, how the transport of methane and the mechanism by which it is transported control the development of persistent, massive hydrate accumulations in deep sediments below the seabed at the Walker Ridge Block 313 (WR313) in the northern Gulf of Mexico. In the first phase of the project, UTA modified an existing reservoir simulator to include microbial methane production, sedimentation, and salt mass balance effects on methane stability. Additional Phase 1 efforts focused on the development of a 1-D reactive transport model to provide constraints on methanogenesis. During the second phase of the project, UTA will focus on simulations of dissolved methane migration mechanisms in order to determine if sufficient flux is available to develop the massive hydrate accumulations observed at WR 313. The final phase of the project will focus on simulations of free methane gas migration and recycling of methane in the gas phase as it is buried below the base of the methane hydrate stability zone.

This project will develop technology and data for the characterization of gas hydrates in the Gulf of Mexico to better understand the impact of hydrates on E&P safety and seafloor stability, aid in understanding the role of hydrates in the global carbon cycle, and provide data to aid in the assessment of marine hydrate as a potential future energy resource.

Source is OSTI

Carbon dioxide (CO2) enhanced oil recovery (EOR) is a well-established method for increasing oil recovery from the Permian Basin oilfields of Texas and New Mexico and more recently in Mississippi oilfields. Typically, 10-15 percent or more of the original oil which is present in a reservoir at the start of production can be recovered using CO2 EOR. A recent study by Advanced Resources International estimated that 64 million additional barrels of oil could be recovered from the Citronelle Field in Alabama using this technique. When production is complete, the reservoir and adjacent formations can also provide sites for storage of CO2 produced from combustion of fossil fuels in power plants and other processes generating large quantities of CO2. The Citronelle Field is an ideal site for CO2 EOR and sequestration, from both the reservoir engineering and geological perspectives. The field is mature and has been waterflooded, with existing infrastructure and deep wells and consists of fluvial-deltaic sandstone reservoirs in a simple structural dome. Because of the presence of the regionally extensive Ferry Lake Anhydrite seal, four-way structural closure, and lack of faulting, it is naturally stable with respect to CO2 storage. However, the geology of the heterogeneous siliciclastic rocks in this field is very different from those where CO2 EOR has been applied commercially, such as in the carbonate strata of the Permian and Williston basins. A demonstration project will show that these reservoirs can be safe and profitable targets for EOR, reducing the risk for small producers. A well publicized injection test and reservoir simulation demonstration will introduce CO2 EOR as an alternative for mature Southeastern oilfields, encouraging its widespread application by independent producers, increasing incremental domestic oil production.

The Groundwater Protection Council (GWPC) plans to update and expand its Risk Based Data Management System by adding new components relevant to current environmental topics such as hydraulic fracturing, increasing field inspection capabilities, creating linkages between FracFocus and state programs, and analyzing potential for data sharing with states. GWPC will also work with the Energy Information Administration on the development of a National Oil and Gas Gateway.

The goal of the project is to provide the next commercialization step for the SPI-CO2 gel system. This will be done by obtaining field data and samples of water and crude oils from multiple operators and fields. We will then perform lab testing on these samples with the SPI gel system for optimal formulations and pore volumes. Field injectivity test designs for three wells/fields will be made and then performed in the field. These field injectivity tests will be designed to prove the capability and impact on the CO2 injection, but are not large enough to be considered a pilot scale field test. The expected result of this project is that these injectivity tests will be sufficient to demonstrate the effectiveness for sweep efficiency improvement, non-damaging nature and ease of use of the SPI –CO2 gel system in CO2 enhanced oil recovery projects.

The overall project goal for the University of Texas at Austin is to develop a new low frequency electromagnetic induction method, which has the potential to estimate not only the propped length, height, and orientation of hydraulic fractures but also the vertical distribution of proppant within the fracture. The proposed low frequency electromagnetic induction tool can be used to detect far-field anomalies in the rock matrix from a single borehole.

This project is to conduct a field-based hydraulic fracturing research program for horizontal shale wells with the objectives of reducing and minimizing potential environmental impacts, demonstrating safe and reliable operations, and improving the efficiency of hydraulic fracturing. The research will advance our understanding of the hydraulic fracturing process in shale reservoirs, and thus, enable the design and execution of effective fracture stages that significantly contribute to production. Improved design and execution of fracture stages will also reduce the number of future infill wells drilled, and reduce water volume and energy input. A smaller environment footprint associated with shale drilling will be the result of this work.

Phase 2: EOR was added to the project, where a series of cyclic gas injections will be performed to increase the oil recovery post initial hydraulic fracturing. The cyclic gas injection experiment will also be accompanied with state of the art diagnostics. Phase 2 will culminate with a core though well and production testing to quantify the production

increase of each gas injection.

Phase 3: Legacy Well Recompletion – Infill Stimulation was added to the project to determine the effectiveness of infill stimulation (fracturing in between existing perforations) for increasing production and recovery rates from existing horizontal wells. Activities will include provision of a field test site containing existing producing wells which will be candidates for in-fill recompletion; drilling of a slant observation well at the test site, including the collection of whole cores, open and cased hole logs, installation of permanent fiber optic cables and discrete pressure gages; monitoring pre-re-stimulation depletion patterns; re-completion of an existing horizontal well using an expandable liner to seal off existing perforations allowing in-fill stimulation, assessment of legacy and in-fill stimulation effectiveness, time-lapse interference testing, assessment of existing and newly created fracture geometry using microseismic and fiber optic data such as DTS, DAS, and DSS, time lapse oil fingerprinting, and public outreach including immediate data dissemination.

General Electric Company plans to develop a novel well-integrity inspection system (Nxis) capable of providing enhanced information about the structural flaws and topology of conventional and unconventional gas wells. To achieve this, a novel combined X-ray/neutron backscatter imaging device will be developed that is suitably sized for operation in well bores. The first phase of the project will focus on validating the subcomponent technologies and the prototype proof-of-concept system. The second phase will be dedicated to multi-modality prototype design optimization and algorithm development, fabrication, and testing. The output from the prototype device will be combined with data from more conventional modalities to achieve accuracy not currently possible.

This project is to provide a long-term field site to develop and validate new knowledge and technology to improve recovery efficiency and minimize environmental implications of unconventional resource development.

Texas Tech University System plans to evaluate oil recovery potentials of cyclic gas injection in shale oil and shale gas condensate wells. The overall technical objectives to be accomplished during the three phases of the project include: (i) studying dominant gas injection mechanisms in shale reservoirs (e.g., pressure maintenance or miscibility); (ii) finding the most effective mode of gas injection in shale oil and gas condensate reservoirs (e.g., gas flooding or huff-n-puff); (iii) exploring the economic value of effective gas injection modes; and (iv) designing and carrying out field pilot tests that demonstrate the proposed technology. The scope of work is split into three groups of studies: (1) maximizing oil production from shale oil reservoirs; (2) maximizing oil production from condensate reservoirs; and (3) Gas injection pore-scale experiments and simulation. For the first two groups of studies, experiments and reservoir-scale simulation will be conducted, and a field pilot test will be carried out. The third group consists of pore-scale studies, designed to yield fundamental new knowledge on gas injection and multiphase flow in fractured shale reservoirs. Particularly, the improvement of sweep efficiency by gas injection compared to water injection will be investigated.

The purpose of this project is to determine whether natural gas, which is available from surrounding well sites or from nearby gas processing plants, can be used as the primary fluid in hydraulic fracturing processes. The project work is focused on developing and demonstrating affordable non-water-based and non-CO2-based stimulation technologies. Such technologies can serve as alternatives to, or be combined with, water-based hydraulic fracturing fluids to reduce water consumption and the volume of flowback fluids. The process will utilize natural gas supplied at wellhead conditions to produce a fluid capable of meeting conditions necessary for injection.

The Ohio State University, Columbus, Ohio, will lead a consortium of researchers and industrial partners in conducting a long-term comprehensive field study on unconventional oil and gas (UOG) development. During the five-year project, researchers will: (1) provide a platform for environmental and geotechnical studies before, during, and after UOG development and (2) address fundamental concerns regarding the environmentally sound extraction of shale gas by creating and managing a Utica Shale Energy and Environmental Laboratory (USEEL)-a field site and dedicated research laboratory in the heart of the Utica Shale play in Ohio. USEEL will make possible a series of research tasks focused on subsurface resources and the environment, all guided by five objectives: (1) augmenting and advancing UOG best management practices, (2) improving the understanding of the nature and impact of UOG resource development on the environment, (3) advancing technology and engineering practices to increase safety and decrease environmental impact, (4) providing data and interpretation in a transparent manner, and (5) providing the public with unbiased scientific results.

General Electric (GE) Power & Water will lead the technical tasks for this project and GE-Global Research (as a sub-awardee) will provide consulting services for materials and cooling assessments. GE will develop their multi-tube mixer combustion technology as an innovative turbomachinery component that contributes towards the DOE goal for advanced gas turbine efficiencies that are greater than 65 percent in combined cycle applications. This project will develop and synthesize GE combustion system with goals of achieving low nitrogen oxide (NOx) emissions up to turbine inlet temperatures of 3100 degrees Fahrenheit while also supporting the load-following needs of a modern grid. Phase I is structured to first push the temperature entitlement by creating an ultra-compact design that minimizes both NOx formation and the surface area that needs to be cooled, followed by a second push that gives the architecture the adjustability it needs to meet the engine load-following requirements. This initial phase will be focused on in-depth engineering analysis and design with a minimal amount of laboratory testing to enable a down-select of the top three combustion architectures. This project will build upon the advancements achieved on an earlier DOE contract, DE-FC26-05NT42643.

This project will perform a detailed geologic characterization and produce a new reservoir model of the largest producing residual oil zone (ROZ) in the Permian Basin, Hess Seminole San Andres Unit, based on core logging, petrography, and stratigraphic correlation of facies using core and wireline logging results. The new ROZ model will be used to design sophisticated multiphase fluid flow simulations to test different injection strategies. The team will compare the cost effectiveness of using a range of different strategies (such as use of horizontal injector wells, strategies to modify the viscosity of CO2 such as foam, and various strategies to alternate CO2 and water during injection) to optimize both oil production and incidental CO2 storage. Recommendations to optimize the sweep of CO2 in the reservoir will be presented to the operator of the reservoir for potential future implementation and testing.

Paulsson, Inc. plans to extend fracture and fracture proppant mapping and monitoring technologies allowing both efficient and environmentally prudent development of unconventional oil and gas resources. Acoustic micro emitters (AME's) will be mixed with proppant in small concentrations and injected into the fractures concurrent with the proppant to track the actual proppant location, then compared with actual fracturing locations. An ultra-sensitive large bandwidth large aperture fiber optic-based borehole seismic vector sensor array will be developed that can be deployed in vertical and horizontal wells to map the fractures and the proppant contained within the fractures. By monitoring the injection process, recording, and locating the microseismic data from both the fracturing of the rock and from the AME's mixed with the proppant, the location, direction, extent, and amount of propped induced fracturing can be determined.

Higher operating temperatures and improved component durability are required to improve the efficiency of power generation turbine engines utilizing fossil fuels. Directed Vapor Technologies International and the University of Pittsburgh will develop high temperature capable thermal barrier coating systems to protect metallic turbine engine components during increased temperature operation.

Terves, Inc. plans to (1) characterize the underlying kinetics and effectiveness of novel stimulation fluids, and experimentally determine the engineering design basis for their use. Methods of controlling the rate and under what conditions (timing) the expansion force is delivered into crack networks will be experimentally verified, and their function and resultant fracture conductivity after stimulation will be measured using American Petroleum Institute reference methods in the laboratory to demonstrate feasibility and support the transition to scale-up and field trials. Through these efforts, the project will aim to develop a new class of swellable proppant particles that can deliver a pumpable formulation that is capable of local application of considerable force to open and extend crack networks for oil and gas, mineral, and geothermal energy extraction from deep hardrock and tight formations. This project will develop the engineering basis for these engineered particles through the development of an experimental understanding of the chemistry, structural design, and response to formation conditions of these force delivery particles. Feasibility will be demonstrated by determining the kinetics and extent of the force-application reactions, and by measuring post-expansion strength and permeability compared to preliminary product specifications. Particles are designed to be non-toxic, and to utilize low cost commodity materials such that the end product can be affordable for use in resource extraction applications.

Novel low cost autonomous hardware will be developed which will collect data which will allow for the detection of CO2 leakage in groundwater. Data from this hardware will be automatically processed to provide real time information to diverse stakeholders about possible CO2 leakage into the groundwater. In Phase I, Subsurface Insights prototype hardware will be enhanced and a fieldable system will be developed. Enhance methodologies which allow for the identification of the data in terms of CO2 leakage will also be developed. Finally, an existing cloud based data ingestion and processing system will be enhanced to receive and process data from the novel hardware.

The University of Utah will team with Amaron Energy to advance the development of Chemical Looping Combustion with Oxygen Uncoupling (CLOU) to pilot scale through the operation and thorough evaluation of performance in an existing pilot-scale, dual fluidized bed chemical looping reactor. Chemical looping combustion (CLC) is recognized as one of the most promising carbon dioxide (CO2) capture-ready technologies for producing energy from coal. The University of Utah has been researching CLC since 2007, focusing on the CLOU variant that involves integrated oxygen production and CO2 separation. Specific objectives include (1) performing CLOU processing of U.S. coals in a pilot-scale, dual bed chemical looping system over a range of conditions, with particular focus on carbon conversion and CO2 capture; (2) scaling up production of low-cost copper-based CLOU oxygen carriers; (3) designing a robust carbon stripper to minimize carbon loss to the air reactor in a dual-bed CLOU system; and (4) developing modeling and simulation tools for improving knowledge of the CLOU process, troubleshooting, optimization, and scale-up.

The rotating detonation engine (RDE) or continuous detonation wave engine is acknowledged by many to be among the most promising pressure gain combustion technology approaches. While initially demonstrated in the 1960s, the highly transient operation, particularly relative to the injection system, has made it difficult to optimize performance. However, recent advances in high-speed data acquisition (including optical and laser-based measurements), combined with vastly improved computational tools, provide an environment suitable to rapidly advance the technology. The project team at Purdue University - along with industry consultant input from United Technologies Research Center (UTRC) - will conduct detailed measurements in both an operating RDE and a simplified system that will quantify key physics important for the design and optimization of RDEs, specifically, in the areas of fuel/air mixing, unsteady injector operation, and turbine integration characterization. The technical approach includes experimental studies (using an optically-accessible injection dynamics facility and a subscale combustor facility) as well as computational fluid dynamics (CFD) modeling analyses. The project team will ultimately work to develop a method to quantify net pressure gain in an operating RDE.

The Georgia Institute of Technology (Georgia Tech) will develop the fundamental knowledge and understanding required for low nitrogen oxides (NOx) combustion concepts that could be applied at very high firing temperatures well above the thresholds where current low NOx combustion approaches are effective, and without compromising operability or carbon monoxide emissions at partial load. This goal will be accomplished through the combined application of detailed kinetic calculations and optimization studies to determine optimum axial injection profiles that enable low NOx operation at elevated temperatures. This work will be followed by experimental work on the emission and operability characteristics of candidate combustor concepts. Computations and laser diagnostics will be used to determine local mixing and heat release characteristics.

This project will be conducted by the Gas Technology Institute (GTI) with support from Media & Process Technology, Inc. (M&P); SmartBurn LLC; and Florida International University (FIU). GTI has developed and patented the Transport Membrane Condenser (TMC) latent heat and water recovery technology—based on a nanoporous ceramic separation membrane—that extracts water vapor from flue gases. Water vapor in the flue condenses and passes through the membrane producing high purity water, and the associated latent heat of condensation can be directly added to the boiler feed water stream. Contaminants and permanent gas components such as carbon dioxide (CO2), oxygen, nitrogen oxides, and sulfur oxides are inhibited from passing through the membrane by its high selectivity. In this project, GTI and development partner M&P will adapt the TMC design for pressurized oxy-combustion utility boilers currently under development. GTI’s pilot-scale fluidized-bed coal gasifier/combustor will be prepared for oxy-combustion operation mode and installation of the TMC. Testing will precisely simulate coal flue gas conditions in a slurry-fed pressurized oxy-combustion boiler. M&P will conduct membrane development work specifically for this high-pressure high-moisture application, and FIU will assist GTI with the new TMC design simulation and performance optimization. SmartBurn LLC will provide expertise and detailed information on power plant operation and analysis for integrating the TMC technology into the plant water use loop, plus a techno-economic analysis for its integration into a power plant. This work builds on previous DOE contracts DE-FE0024092 and NT0005350.

The University of Pittsburgh (Pitt), with support from West Virginia University (WVU), will develop an innovative approach to immensely improve the level of thermal protection for hot-section components—such as turbine airfoils—in modern and future gas turbines. The approach will make use of oxide dispersion strengthened (ODS) material to form a thermal-oxidation protection layer over a single crystal superalloy substrate, in conjunction with the concept of near-wall cooling. This research includes four inter-related project objectives: (1) design highly heat-transfer augmented and manufacturable internal cooling channels for the development of near surface embedded cooling channels (NSECC); (2) produce ODS particles between 45 and 105 microns, which will be used in an additive manufacturing (AM) process based on laser deposition to build NSECC test modules; (3) develop a fabrication process through AM for coating either a densified ODS layer over a grooved single crystal superalloy substrate to form an enclosed NSECC or an ODS layer with cooling channels embedded within the ODS layer atop a single crystal superalloy metal substrate; and (4) characterize the thermal-mechanical material properties and cooling performance of the AM produced ODS-NSECC protective module under high-temperature conditions. Pitt will be responsible for all the tasks pertaining to fluid flow and heat transfer and will also contribute to the manufacturing front and develop ODS coating techniques. WVU will be responsible for producing ODS particles (powder) for the laser deposition process at Pitt as well as perform thermal cyclic testing on AM-built ODS components in both dry- and wet-air environments. Microstructures at the interface between the ODS and substrate will be jointly examined.

The Georgia Institute of Technology (Georgia Tech) project will focus on key knowledge gaps associated with supercritical carbon dioxide (SCO2) oxy-combustion at high pressure (up to 330 atm) conditions—namely, experimental studies of fundamental autoignition properties, development of an optimized chemical kinetic mechanism, and numerical and theoretical analyses of flow, mixing, and flame dynamics. The project has three basic objectives: (1) measurement of autoignition delays of CO2 diluted oxygen/fuel mixtures (natural gas and syngas) in a high-pressure shock tube (the experimental conditions cover pressures from 150 to 330 atm and temperatures from 1100 to 1800 K); (2) development of an optimized compact chemical kinetic mechanism for SCO2 oxy-combustion based on the data obtained; and (3) numerical and theoretical investigation of SCO2 oxy-combustion at pressure using the kinetic mechanism developed.

The University of Kentucky Center for Applied Energy Research (UK-CAER) will assess and validate an advanced coal-fueled pressurized chemical looping combustion (PCLC) technology that adopts a novel spouted bed to avoid OC (oxygen carrier) agglomeration, improve plant efficiency and reduce process complexity. The scope of the project will be the designing, fabricating, and testing of an integrated coal-fueled pressurized facility at lab scale, which uses an industrial byproduct-based oxygen carrier as a cost-effective cycling material, pulverized coal as a feedstock, and a novel spouted bed reactor as the reducer. Research will include collecting various data and information to address the major technical gaps of solid-fueled PCLC technology. The project will be conducted over two budget periods. Budget Period 1 consists of process design, modification of the existing novel spouted bed facility at UK-CAER, and cold commissioning prior to hot testing. Budget Period 2 includes hot testing, data collection, and performance evaluation of the PCLC facility. Trimeric Corporation will perform a techno-economic assessment of a commercial unit. This work builds on previous DOE contract FE0024000.

This research project will demonstrate a wireless, high-temperature sensor system for monitoring the temperature and health of energy-system components. The active sensor and electronics for passive wireless communication will be composed entirely of electroceramic materials (conductive ceramics), which can withstand the harsh environments of fossil-energy-based technologies. This work will focus primarily on the direct-writing and testing of temperature (thermocouples and thermistors) and health (strain/stress and crack propagation sensors) that function between 500 and 1,700 degrees Celsius. A peel-and-stick-like transfer process to deposit the entire sensor circuit to various energy-system components will be developed. NexTech Materials, Ltd., and General Electric Global Research will collaborate and consult on the proposed demonstrations of the technology. These sensor systems may be applied to many systems, such as solid oxide fuel cells, chemical reactors, furnaces, engines, boilers, and gas turbines (for both energy and aerospace applications).

This project will interface NETL's Multiphase with Interphase exchanges (MFIX) code with Portable Extensible Toolkit for Scientific Computation (PETSc) and High Performance Preconditioners (HYPRE) linear solver libraries with the goal of reducing the time to solution for the large, sparse, and often ill-conditioned matrix equations resulting during the solution process. The lack of robust convergence associated with the current iterative methods in MFIX can be alleviated through appropriate preconditioning techniques to Krylov Subspace solvers and Multigrid methods accessible from these third-party solver libraries. Interfacing MFIX with the third-party linear solver packages will first be accomplished by establishing a robust, well-abstracted solver interface that can be activated at compiling time, using appropriate compiler directives based on local availability. This would allow the utilization of several third-party solver packages or none at all, thus maintaining the current operability of MFIX.

Carnegie Mellon University will design, characterize, and demonstrate wireless, conformal strain and pressure sensors manufactured using low-cost, direct write additive methods for application in fossil energy (FE) systems. The goal is to demonstrate the feasibility of low-cost aerosol jet manufacturing for FE systems and to develop next-generation sensors and controls that can sustain temperatures up to 500 degrees Celsius (°C).

Specifically, this project will advance the current state of the art by developing novel materials and devices for wireless circuits that surpass 350 °C—the operating temperature limit of traditional silicon-based electronics—integrating electronic circuitry on curved three-dimensional surfaces such as those observed in gas turbine engines, demonstrating capabilities that surpass those of traditional (two-dimensional) lithographic techniques; and improving reliability issues for wireless sensors that arise from the demanding FE environments.

The University of Central Florida (UCF), with support from Stanford University and Embry-Riddle Aeronautical University, will develop and validate a combustion chemical kinetic mechanism for supercritical carbon dioxide (SCO2) oxy-combustion that can be used for computational fluid dynamics (CFD) simulations in oxy-combustion development. This model will be validated via experiments conducted in CO2diluted methane/syngas mixtures and at pressures up to 300 bar. Researchers will use shock tube and laser diagnostics to make detailed measurements of ignition times and species concentrations in non-reacting and reacting methane/syngas mixtures in CO2 dilutions covering a wide range of pressures up to 300 bar. The model will then be implemented in an open source CFD code and disseminated to industry.

The Pennsylvania State University (PSU) will investigate the effect of mixture concentration inhomogeneity on detonation propagation. The goal is to gain fundamental understanding of the relationship between mixture inhomogeneity and detonation properties to improve the design of pressure gain combustion systems with a focus on flow configurations found in rotary detonation engines. In most rotary detonation engine designs, fuel and oxidizer are separately injected into the main combustion chamber, leading to spatial variations in fuel and oxidizer concentration (mixture inhomogeneity) prior to the onset of detonation. Rotary detonation engines are particularly prone to concentration variations due to short mixing times and variations in fuel and oxidizer flow rates due to backpressure from the continuously traveling detonation wave. The interaction between the detonation wave and these variations in concentration can lead to reductions in the detonation wave velocity, local increases in pressure fluctuations, and changes in the failure limits of successfully propagating waves.

The University of Michigan will research the physics of non-ideal effects in practical rotating detonation engines (RDEs) that impede the realization of theoretical detonation cycle efficiencies and operability. RDEs that use detonation-based compression are considered superior to the external compressor-based Brayton cycle engines because of their ability to use shock-based compression to increase pressure of the fluid in the combustor, which leads to a gain in thermal efficiency (pressure gain). Combined with conventional compressors, such devices promise significantly higher overall efficiencies compared to traditional cycles. RDEs and other similar variants for turbine engine applications have been studied for many decades, and several lab- and medium-scale devices have been built. The main issues that prevent large-scale and practical use of RDEs arise from the non-idealities associated with imperfect mixing and detonation structure. Currently, there are no design guidelines on how to overcome or account for these non-idealities. In this work, the project team will use detailed experimental measurements and computational tools to research the source or cause of such non-idealities from a fundamental physics point of view and link them to RDE performance. The goal of this work is to take a fundamental point of view and use detailed experiments and simulations to understand non-ideal effects and their contribution to loss in pressure gain.

NETL is partnering with Electric Power Research Institute Inc. to qualify improved high-performance structural materials for application in current power plants in order to improve flexibility. The project will (1) develop the needed microstructural processing and performance relationships and associated material models for specific constituents in fabricated weldments (such as the parent material, heat affected zone regions, and weld metal); (2) apply these metallurgical relationships through modeling to a composite welded component subjected to cyclic operational conditions under both mechanical and thermal loading; and (3) validate the model through novel structural feature and component tests. The project will make a significant impact in the technical community by improving existing mainstay creep stength-enhanced ferritic steels operating under flexible operation modes.

This project will improve performance of the MFIX-DEM code to enable a transformative shift for industrial use. The current simulations fall short of the O(108) particle simulations that must be completed on a timescale of days to enable simulations with physically-relevant domain sizes to be incorporated into industrial design cycles within five years. The team will accomplish this by tailoring best-in-class practices to bear on the challenges posed by the MFIX-DEM algorithm and code base. The MFIX-DEM code will be refactored to minimize data movement and synchronization between the Eulerian and Lagrangian updates. This will facilitate optimization of the particle update to expose multiple levels of parallelism, allowing the algorithm to map onto highly-parallel accelerators such as many-core architectures and GPU's, thus the code will run efficiently from the workstation to supercomputer. The proposed approach will enhance MFIX DEM by using a profiling methodology to identify numerical and algorithmic bottlenecks. Both serial and parallelization bottlenecks will be overcome via vectorization, cache utilization, algorithmic improvements, and implementation of hybrid MPI/OpenMP parallelization methods that synergize with current heterogeneous high performance computing (HPC) architectures and accelerators. Optimizing MFIX-DEM and implementing parallelization for accelerated HPC systems will enable simulations of industrially relevant problems and on machines that industry are likely to have in the coming years. The ultimate goal is to achieve a speedup of two orders of magnitude; a refined estimate will emanate from the profiling effort. Based on our preliminary findings and recent work, a realistic goal for Phase 1 is a performance improvement and demonstration on an industrially-relevant simulation involving 108 particles. Regarding the latter, the team will survey over 30 PSRI member companies during the beginning of the project to identify industrial needs. New experiments will be performed involving ~108 particles in a system of industrial relevance, and this experiment will be used to demonstrate the enhanced MFIX code. Uncertainty quantification (UQ) will also be performed by coupling the available UQ toolkit PSUADE with enhanced version of MFIX. UQ using the enhanced MFIX code on larger and industrially relevant systems will be demonstrated.

Washington University in St. Louis (WUSTL) will investigate integrated pollution removal (IPR) with simultaneous latent heat recovery from flue gas for a staged, pressurized oxy-combustion (SPOC) system. The objectives are to (1) assemble and test a bench-scale experimental system which will allow for detailed study of reaction kinetics of sulfur oxides (SOx) and nitrogen oxides (NOx) removal in a prototype wash column at desired temperatures and pressures, and (2) design and construct a packed bed, counterflow column which will serve as a prototype device to test and demonstrate SOx and NOx capture with simultaneous recovery of heat from flue gas moisture condensation. This prototype will be installed at the 100 kilowatt (kW) pressurized furnace at WUSTL. The project will (1) evaluate the performance of the prototype column using both simulated flue gas and real flue gas generated in the 100 kW SPOC facility, and (2) obtain experimental data from the bench-scale system and measure the effects of key process variables on the SOx and NOx capture efficiency, and develop an accurate reaction mechanism model which could be used to design future pilot-scale and ultimately commercial-scale systems. This project will leverage on-going research results from DOE project FE0009702.

The objective of this research by The Ohio State University (OSU) is to explore innovative cooling architectures enabled by additive manufacturing techniques to improve cooling performance and reduce coolant waste. The ability to create complex internal geometries will be leveraged to better distribute coolant through microchannels, as well as to integrate inherently unstable flow devices to enhance internal and external heat transfer. Fundamental experiments will be conducted initially to demonstrate and test each of the technologies at large scale and low speed, as well as to determine optimal geometries and operating conditions. These experiments will reveal the most promising and feasible technologies, which will subsequently be incorporated into stereolithography turbine vanes to be tested at appropriate Mach numbers in a high-speed cascade facility. Four cooling schemes have been identified for investigation: fluidic oscillators as pulsed impingement jets, fluidic oscillators as sweeping film cooling holes, micro-channel surface cooling, and reverse film blowing. Finally, a full material system will be demonstrated using a thermal barrier coated, metal deposition fabricated (using Direct Metal Laser Sintering) turbine vane tested at high speed and under high temperature in the turbine test facilities at OSU. The experimental work will be accompanied by a computational fluid dynamics (CFD) study at each stage. These CFD simulations will enable the exploration of a broader design space during the optimization stage, as well as extrapolation to higher temperatures and pressures not possible in the turbine test facility in the final stages. This project leverages previous research under DOE contract DE-FE0007156.

The Southeast Offshore Storage Resource Assessment (SOSRA) project is assessing prospective geologic storage resources for carbon dioxide (CO₂) in state and federal waters of the Mid-Atlantic, South Atlantic, and the eastern Gulf of Mexico (Figure 1). The project is defining the size and geology of the prospective storage resources (including areal extent, thickness, and physical properties such as porosity and permeability) using existing geologic and geophysical data, such as seismic reflection surveys, geophysical well logs, and supporting reservoir data (pressure, temperature, etc.). A diverse suite of data analysis techniques is being used to ensure that a high-quality assessment is performed to meet the goal of predicting storage capacity to within plus/minus 30 percent. The analysis started with a survey of available knowledge to provide an overview of the basic geologic framework of the project regions, identify potential storage units in those regions, and define the key planning areas. The initial phase of work concludes with a comprehensive analysis of available data that includes a quality and coverage assessment. The second phase of work continues characterization of offshore CO₂ storage opportunities, performs a volumetric CO₂ storage assessment, contributes to the development of best practices, and identifies economic and technical barriers that must be addressed or avoided to ensure timely deployment.

There is a present and growing emphasis on reducing or maintaining

the water-use footprint in the energy sector. One of the requirements for effectively managing water is

monitoring through reliable, real-time, measurement-based data of water quality/composition within

treatment systems and bodies of water associated with power generation facilities. Many existing water

quality sensor technologies are expensive, large, difficult to install or deploy, and expensive, which

inhibits utilities’ ability to deploy a network of such sensors. What is needed is the development of an

integrated water sensor package that is low-cost, rapidly-deployable, wireless, and self-powered, that

can relay real-time relevant in-situ water measurements. Ideally such hardware would simultaneously

monitor multiple water quality factors and contaminants at a reduced overall cost.

Sporian proposes to heavily leverage our mature water quality

monitoring sensor and sensor system technology/hardware, which includes many of the needed water

quality sensor types, and extend the sensing capability of the systems to include heavy metal

contamination (RCRA 8s) through the use of Imprinted Polymer (IP) based detection materials/schemes.

The proposed technology will support reducing or

maintaining the water-use footprint in the energy sector, providing low cost to deploy, reliable, realtime,

measurement-based data for water management. Such a technology will be highly attractive for

broad application within energy, industrial/agricultural, and civilian drinking water and wastewater

monitoring sectors that require sanitary water for consumption or whose processes affect water and

need a sensor to assure proper contamination monitoring and abatement.

The project is developing and validating pressure management and CO2 plume control strategies that can address technical and economic barriers to commercial deployment of carbon capture and storage technologies based on computational and field demonstration work at two Illinois CO2 storage sites (the Illinois Basin Decatur Project and the Illinois Industrial Carbon Capture and Storage Project). New and existing wells are being used to investigate field-ready development and monitoring strategies to manage pressure and control CO2 plumes. The effort is evaluating extraction well(s) placement, brine-extraction-to-CO2-injection ratios, extraction well completions, and brine treatment and handling options (Figure 1). The sensitivity of pressure changes and CO2 plume movements to extraction well location and brine-extraction-to-CO2-injection ratio is being evaluated via reservoir simulations. Both storage efficiency and a differential pressure index are being used for selecting effective brine extraction strategies. Brine treatment and handling methods that account for safe handling of brine from extraction through treatment and eventual use in industrial settings (water life-cycle analysis) are being considered. The most practical or promising brine treatment and handling options will be recommended for implementation when this project advances to a second phase.

The objectives of this project are to: 1) address research and technological gaps and reduce commercial-scale geological CO2 risks by developing and validating, through a carefully-designed field project, advanced technologies and engineering approaches for predicting, monitoring and managing pressure plumes; and 2) to develop a Brine Extraction Storage Test (BEST) that will deploy treatment technologies for extracted brine water. This project is focusing on the use of the Rock Springs Uplift (RSU) carbon storage site in southwest Wyoming (Figure 1).

The University of Texas at Austin is utilizing existing data (well logs, records and sample descriptions from existing or plugged/abandoned wells, available seismic surveys, existing core samples, and other available geologic and laboratory data) from historical hydrocarbon industry activities in the heavily explored areas of the inner continental shelf portions of the Texas and Louisiana Gulf of Mexico coast (Figure 1) in order to assess the storage capacity of depleted oil and natural gas reservoirs. Additionally, they are assessing the ability of saline formations in the region to safely and permanently store nationally-significant amounts of anthropogenic CO2. The project is identifying at least one specific site that could be considered for a future commercial or integrated demonstration project with the ability to store at least 30 million tons of CO2. The study is undertaking a regional geologic characterization of the stratigraphy of the Texas and western Lousinana offshore regions to provide a detailed assessment of CO2 storage opportunities.

Boston University (BU) will design solid oxide fuel cell (SOFC) anodes that are functional at intermediate temperatures and maintain high power densities at high fuel utilization, which is accompanied by high water vapor concentrations at the anode. BU will demonstrate the ability to deposit fine nano-sized connected nickel (Ni) catalyst particles by infiltration into porous yttria stabilized zirconia (YSZ) and YSZ/Ni scaffolds to increase triple phase boundary length. Project personnel will optimize the anode microstructure based on quantitative microstructural characterization, polarization measurements, and modeling. The result will be the production of SOFC cells that demonstrate a substantial improvement in cell performance at intermediate temperatures and high fuel utilization rates compared to cells with conventionally processed anodes. The challenge is to deposit them in a fine, but connected microstructure, with substantial neck formation during sintering without significant coarsening. This project leverages previous related work under DOE contracts NT0004104 and FE0009656.

The objective is to complete the planning activities and the front-end engineering design (FEED) needed for conducting a full-scale pilot of select components at high-temperature and pressure at advanced ultra-supercritical (AUSC) conditions in the steam-turbine portion of a Component Test (ComTest) facility. These components will be made from advanced nickel-based materials identified and developed during a jointly-funded, multi-year DOE and Ohio Coal Development Office (OCDO) AUSC Consortium. The ComTest program will: 1) evaluate advanced materials and components under coal-fired AUSC conditions, demonstrate the reliability and safety of the boiler components; 2) demonstrate steam-turbine operation and valve reliability at AUSC conditions; 3) provide better understanding of the cost of an AUSC power plant to reduce project financial risk; 4) evaluate the constraints in the supply chain for advanced materials, including all necessary components, instruments, valves, and fittings; and 5) validate the fabrication techniques of the nickel alloys and the ability to construct, install, and reliably repair test components on site.

The Pennsylvania State University (Penn State) will conduct the project with support from industrial partner GE Global Research (GE). A three-step approach to understand, and eventually predict, unstable combustion resulting from transient operation will be used. Transients in equivalence ratio, fuel composition, and fuel splitting will be studied. Three transient characteristics will be considered when designing each transient test: transient timescale, transient amplitude, and transient direction. The first step toward quantifying the impact of transients on combustion stability will be to map relevant timescales in the combustion system at steady-state operation under a variety of target conditions. These target conditions will be selected with input from GE and represent operating conditions of interest for industrial gas turbine engines. Once the target conditions are established, four timescales of interest will be measured: heat-transfer timescales, chemical timescales, flow timescales, and acoustic timescales. The second step will be to collect data during transient events, where the transient events are designed to mirror key timescales and operating conditions that were measured in the first portion of the study. The final step will be to analyze the data in order to both understand fundamental combustion behaviors in response to transients and identify precursor signals during the transient before unstable combustion arises. Analysis of these high-fidelity data will enable descriptions of the nonlinear behaviors that occur during transients, as well as important characteristics about the beginning and end states of each transient.

Battelle Memorial Institute developed a prospective resource assessment for carbon dioxide (CO₂) storage in offshore regions along the mid-Atlantic and northeastern United States (Figure 1). The systematic carbon storage resource assessment region extends from the Georges Bank Basin through the Long Island Platform to the southern Baltimore Canyon Trough. Key input parameters were defined to reduce uncertainty of efficiency estimates and risk factors that may constrain the storage resources assessment. Industry and regulatory stakeholders were engaged through a roadmap development effort designed to assist future project planning and implementation.

The Ohio State University (OSU) will team with WorleyParsons (WP) to continue development of its chemical looping gasification (CLG) technology—an advanced air separation process that can be applied to produce electricity via integrated gasification combined cycle (IGCC) while achieving greater than 90 percent carbon capture and/or to produce chemicals via traditional catalytic reforming processes. Researchers will validate the feasibility of applying CLG technology by demonstrating the CLG process at a sub-pilot scale and conducting a techno-economic analysis of its applications for IGCC. A cumulative demonstration of greater than 100 hours will be performed with the 15kWth sub-pilot test unit to confirm the reliability of the reactors (reducer and oxidizer) and non-mechanical devices for maintaining controlled solid circulation, gas sealing, and coal distribution in the reactor (reducer) as well as to confirm sustained syngas production performance. OSU—with the support of WP—will conduct a comprehensive techno-economic analysis of the CLG process for IGCC application and compare it to the DOE baseline IGCC report. A highly reactive and attrition-resistant oxygen carrier was confirmed for chemical looping gasification applications in a previous Department of Energy funded project, DE-FE0012136.

Alstom Power Inc. (Alstom) is developing a limestone-based chemical looping combustion (LCL-C™) process for generating power that will achieve near-zero emissions and include carbon dioxide (CO2) capture. Alstom will team with the University of North Dakota and Envergex, LLC to conduct parametric bench-scale tests, data analysis, and facility modification and operation. Great River Energy will provide industrial input in designing and operating a coal-fired LCL-C™ system. Specific project objectives are (1) parametric testing to select oxygen carrier systems with enhanced reactivity; (2) validation of enhancement of oxygen carrier systems at Alstom 100 millimeter pilot-scale testing facility; (3) integration of an optimized solution in Alstom's 3-MWth test facility with validation of performance; (4) Aspen modeling of the LCL-C™ gas processing unit system for optimization of the species separation and recycling scheme; and (5) a techno-economic analysis update of LCL-C™ technology for power generation to show that the improvement has the potential to meet the DOE cost and performance goals. This program will leverage previous research from DOE Award FE0009484.

GE Global Research, in cooperation with Pennsylvania State University, will leverage new technology to develop a cost-effective water recovery process from high salinity extracted formation water. The project objectives are to: define a scalable, multi-stage extracted water desalination system that yields clean water, concentrated brine and, optionally, salt from saline brines (180,000 ppm total dissolved solids, TDS) and that meets a cost target; validate the overall system performance with field-sourced water using GE pre-pilot and lab facilities, and define the scope and identify a team and test location for pilot-scale implementation of the desalination system. Carbon sequestration facilities will be screened to identify a potential source and composition of extracted water, as well as to identify a partner with whom GE will conduct a pilot water recovery project (Phase 2, separate project). Based on the extracted water composition, a cost-effective water recovery process comprising pretreatment, brine concentration, and, optionally, salt crystallization, will be developed based on techno-economic modeling, which includes rigorous process modeling based on Aspen Plus/OLI systems software. A combination of established and new, pilot-ready pretreatment and brine concentration technologies will be evaluated with respect to cost and performance in order to identify the most cost-effective water recovery process.

GTI (formerly Aerojet Rocketdyne), the government of Canada, and Linde, will develop and test pilot-scale technologies that will focus on improving the economics of the current oxy-combustion pathway as well as addressing technology gaps associated with scale-up and system performance for both atmospheric- and pressurized oxy-combustion technology pathways in the DOE NETL program portfolio. The proposed project will integrate key design modifications into the current oxy-fired pressurized fluidized bed combustor (Oxy-PFBC) pilot plant, located at the government of Canada’s CanmetENERGY laboratory in Ottawa, Canada. The Canadian Clean Power Coalition will provide funding for testing of Canadian coals. The technologies and their specific objectives are (1) In-bed supercritical carbon dioxide (SCO2) Heat Exchanger (HEX) (quantify SCO2 heat transfer coefficients and pressure drop in an Oxy-PFBC environment to anchor design rules for scale up); (2) Staged coal combustion (develop design rules for placement of staged coal combustion injectors to appropriately distribute heat throughout the bed to maintain an oxidizing environment and avoid slagging); and (3) Isothermal Deoxidation Reactor (IDR) (define operational limits on flue gas O2 concentration for an isothermal catalyst bed and demonstrate heat recovery from this deoxidation unit). The test program will leverage the 1 megawatt oxy-PFBC pilot plant from DOE contract DE-FE0009448.

This project aims at developing a wireless integrated gas/temperature microwave acoustic sensor capable of passive operation (no batteries) over the range 350 degrees Celsius to 1,000 degrees Celsius in harsh environments relevant to fossil energy technology, with specific applications to coal gasifiers, combustion turbines, solid oxide fuel cells, and advanced boiler systems. The proposed wireless sensor system is based on a surface-acoustic-wave sensor platform that is configured using a langasite piezoelectric crystal with Pt/Pd interdigital electrodes and yttria-stabilized zirconia films doped with Pd, Pt, or Au nano-catalysts to detect H2, O2, and NOx gases and to also monitor the gas temperature in the harsh environment. Fully packaged prototype sensors will be designed, fabricated, and tested under gas flows of H2 (< 5 percent), O2, and NOx in laboratory furnaces, and the sensor response will be characterized for sensitivity, reproducibility, response time, and reversibility over a range of gas temperatures.

Ohio University along with West Virginia University, and American Electric Power, will validate the technical/commercial promise of an advanced multistage process for treatment and reutilization of impaired water as make-up water in fossil fuel-based power plants through small scale testing and prepare the technology for a future pilot scale test effort, if successful. The process is based upon an advanced multi-stage treatment process which utilizes commercial solids filtering and ultra violet light treatment to remediate bacteria, a low-cost natural zeolite to remove naturally occurring radioactive material (NORM) found in oil/gas-based impaired water, electrochemical stripping (E-stripping) and selective sulfation to remove minor constituents, and a breakthrough supercritical water unit design which utilizes internal Joule-based heating to remove major constituents and hydrocarbons.

The University of Maryland (UMD) will experimentally collect data under real working conditions to achieve solid oxide fuel cell (SOFC) performance optimization, especially with respect to extended service time. The work will develop novel in-operando isotope exchange apparatuses for the investigation of the oxygen surface exchange properties of SOFC cathode materials and structures that will allow the selection of enhanced cathode compositions and structures. Using in-operando techniques, researchers will quantify oxygen reduction reaction (ORR) kinetic rates and mechanisms as a function of cathode composition, gas environment, and applied cell bias to achieve a comprehensive understanding of the ORR properties of cathode materials as a function of cathode composition for lanthanum strontium manganite (LSM) and lanthanum strontium cobalt iron oxide (LSCF) powders and their composites with yttria stabilized zirconia (YSZ) and gadolinia doped ceria (GDC). UMD will also use two in-operando techniques to develop a unifying theory for the numerous surface exchange coefficients in the literature to strengthen the link between fundamental kinetic studies and real world cathode performance. This project leverages research from a previous DOE contract, DE-FE0009084.

Montana State University (MSU) will develop, characterize, and refine electrode preparation methods to mechanically strengthen the anode support structure and facilitate the binding of sub-micron nickel metal catalysts (diameter < 100 nm) to ion-conducting ceramic scaffolds. Researchers will accomplish this task through the addition of reactive materials in low concentrations that chemically join the percolated ion and electron conducting networks comprising solid oxide fuel cell (SOFC) cermet anodes while simultaneously immobilizing metal catalysts to their support. These 2° phase chemical anchors will serve two distinct purposes: (1) inhibit particle coarsening and other mechanisms that deactivate high surface area catalysts at high temperatures and (2) improve the electrode’s fracture toughness and, hence, flexural strength, thus conferring additional mechanical stability to the entire membrane electrode assembly.

This project aims to identify market opportunities for the Carbon Capture Simulation Initiative (CCSI) tools combined with existing gPROMS platform capabilities, including carbon capture and storage (CCS), advanced energy, and cross-sector applications. The research will assess and rank the CCSI tools according to their commercial potential, technical feasibility, and technology readiness level when integrated with gPROMS platform capabilities; develop detailed integration plans and commercialization plans for promising tools, drawing on technical expertise from Process Systems Enterprise (PSE) and the project team, as well as the PSE client base and industrial advisory board structures; and research suitable applications across advanced energy systems and further afield (prototypes will be built during Phase I to evidence and publicize potential).

Arizona State University, along with Lawrence Livermore National Laboratory and Sandia National Laboratories, will address the enhancement of computational fluid dynamics (CFD) coupled with a discrete element method (DEM) in the open-source-code Multiphase Flow with Interphase eXchanges (MFiX-DEM), which is developed and maintained by the National Energy Technology Laboratory (NETL). The objectives of the project are to improve the performance and physical modeling capabilities of MFiX-DEM while tightly integrating these improvements with an intuitive graphical user interface (GUI) driven by an uncertainty quantification (UQ) framework, and to effectively pave the way to wider and more rapid industrial adoption of MFiX-DEM.

The University of Southern California has teamed with Media and Process Technology Inc. and the University of California – Los Angeles to perform laboratory-scale testing of a high-efficiency, low-temperature reactor process for the water gas shift (WGS) reaction of coal syngas for pre-combustion carbon dioxide (CO₂) capture in integrated gasification combined cycle (IGCC) systems. The process will utilize a unique membrane- and adsorption-enhanced WGS reactor system previously developed for hydrogen (H2) production via methane steam reforming that allows for in-situ preferential H2 permeation and simultaneous CO₂ adsorption. The system combines a membrane reactor (MR) and an adsorptive reactor (AR) in tandem to produce an ultra-pure H2 product continuously until the adsorbent (in the AR unit) is saturated, which is then regenerated via a temperature swing adsorption (TSA) operation. This unique reactor configuration can be viewed as a hybrid MR-AR system under TSA operation. The MR-AR system is a highly-efficient and ultra-compact process for the treatment of syngas to produce H2 appropriate for use in IGCC with simultaneous pre-combustion CO₂ capture. Further the use of a temperature-swing rather than a pressure-swing CO₂ recovery step (as commonly practiced in AR systems) allows the recovery of CO₂ at high pressures, thus requiring no additional re-compression step for CO₂ storage. The project goal is to validate the novel hybrid MR-AR system for IGCC applications by conducting laboratory-scale studies using simulated coal-derived syngas. The development effort will use a previously developed carbon molecular-sieve-based membrane and will test a hydrotalcite-based adsorbent and other potentially promising adsorbents. A mathematical model will be used to analyze the resulting data, further optimize the system, develop preliminary technical designs, and conduct a techno-economic analysis.

Air Products and Chemicals, Inc. (Air Products) researchers will conduct research and a feasibility investigation into using a two-phase dense fluid expander (DFE) to improve the overall efficiency of cryogenic air separation. The first objective of this work is to better understand the limitations associated with two-phase dense fluid expansion from aerodynamic, thermodynamic, and mechanical perspectives. The second objective is to apply this knowledge to construct a prototype device to further explore the basic properties of two-phase dense fluid expansion while collecting primary data for techno-economic analyses. This project will be executed in two phases: Phase 1 will comprise a feasibility investigation of three different applications of two-phase DFEs and, in Phase 2, a prototype device will be designed, fabricated, and tested to further prove the feasibility of commercial applications of DFEs operating in two-phase service.

The goal of this project is to develop a high-fidelity and user-friendly multiphase simulator based on the Multiphase Flow with Interphase eXchanges (MFiX) software package, a multiphase computational fluid dynamics (CFD) software developed by the U.S. Department of Energy (DOE) and widely used by the fossil fuel reactor communities.

This work will leverage the linear solver libraries from Trilinos packages and open-source software packages developed by Sandia National Laboratories. Trilinos packages provide easy to use and scalable applied mathematics libraries suitable for massively parallel computers and are kept up to date for the latest hardware, including graphics processing unit (GPU) acceleration. To achieve this, the project will devise a framework to integrate the MFiX linear solvers with the Trilinos linear solver packages (Trilinos MFiX), evaluate the performance of the state-of-the-art preconditions and linear solvers, and test Trilinos MFiX with the MFiX suite of problems on massively parallel and cloud-based computers with and without GPU acceleration.

Praxair will team with Georgia Institute of Technology (Georgia Tech) to perform bench-scale testing of a sub-ambient air separation process based on a rapidly cycled pressure swing adsorption (RCPSA) system that removes a bottleneck from a traditional cryogenic air separation unit. Hollow fiber-sorbent contactors will be used for the sorbent materials. On the lab scale, these have been shown to be 3 to5 times more productive than traditional adsorbent contactors and have a pressure drop 3 to 5 times less than that of standard contactors. A key feature of this process is the ability to perform efficient heat integration, enabling recovery of much of the energy required for gas cooling. One of the key goals of this project is to determine the optimum process structure. Researchers will fabricate hollow fiber contactors and generate sub-ambient isotherms for these materials. They will also perform RCPSA experiments on the fibers and assess the efficacy of an internal phase change material. The RCPSA experimental results will be incorporated into a process model that feeds into a detailed techno-economic assessment. A large prototype module of approximately 100 fibers will be tested to provide insight into module scale-up. Praxair will manage the project and lead the techno-economic analysis. Georgia Tech will perform the fiber spinning and RCPSA experimental work.

The goal of this project is to develop an advanced autonomous control architecture and imaging and optimization sensor information for The Ohio State University (OSU) chemical looping processes. To automate these dynamic, nonlinear systems, a hybrid controller consisting of decision making and controller-selection logic (high level controller; HLC) integrated with sliding-mode controllers (SMCs) will be used to develop a distributed intelligence automation scheme for the chemical looping process startup and shutdown.

The intelligent process automation controller and optimization software will be tested in OSU’s existing sub-pilot chemical looping test unit for Phase I, and ultimately integrated with the pressurized syngas chemical looping (SCL) pilot test unit constructed at the National Carbon Capture Center (NCCC) for Phase II. Additionally, electrical capacitance volume tomography (ECVT) sensor software will be developed to image a packed moving bed of oxygen carriers at the operating temperatures of the reducer reactor. The successful development of the imaging sensor software will be tested and verified in an existing bench-test apparatus and incorporated into the chemical looping sub-pilot test unit for Phase I.

LG Fuel Cell Systems Inc. (LGFCS) will team with Carpenter Technology Corporation (Carpenter) to qualify a material and advanced manufacturing process solution for selected metallic components of an advanced integrated stack block that is the heart of the LGFCS solid oxide fuel cell (SOFC) system. It is intended that these cost reduced components will also increase the reliability and endurance of the LGFCS cell and stack technology. Specific objectives are to identify and validate a material solution for the hot metal components with foresight on how the components will be mass produced, validate the new process solution for making quality parts that will meet product cost targets, and demonstrate that the new material and components do not adversely impact stack performance while operating on natural gas. An integrated material set and processing solution will be developed using powder metals processing which has proven to be an enabling technology capable of delivering net or near net shape components as well as for creating compositions, microstructures, and properties that are otherwise unattainable. Researchers will screen a number of advanced manufacturing processes and select one or more that are most advantageous for producing selected metallic components at commercial volumes. This work will be accomplished through collaboration of metallurgists and processing engineers from Carpenter with product design and cost engineers from LGFCS. The project team will test a full-scale integrated stack block using components from the new material set and processing solution to confirm its readiness for commercial field deployment. This project will build on previous DOE funded work; most recently DE-FE0023337.

West Virginia University (WVU) will use Atomic Layer Deposition (ALD) coating and pre-operation thermal treatment on commercial solid oxide fuel cells (SOFCs) to tailor the nanostructure on anode surfaces. ALD techniques and engineered anode surface architecture will be applied to the inherently functional fuel cells using the commercial available ALD systems. Researchers will identify the key nanostructure engineering processes necessary to improve the performance of state-of-the-art commercial SOFCs. The specific project objectives are to enhance the electro-catalytic activity and cell durability of commercial cells through: (1) the formation of single-phase discrete nano-crystals of a protonic conductor, on the internal surface of Ni/YSZ anodes, (2) the deposition of single phase electro-catalysts, on the internal surface of Ni/YSZ anodes, and (3) the formation of a dual-phase nano-composite scaffold consisting of a nano protonic conductor network and nano-catalyst, on the internal surface of Ni/YSZ anodes.

NETL is partnering with GE Power (Alstom Power, Inc. prior to the merger of Alstom Power and GE), Steam Power Systems to develop a design for testing a high-temperature nickel-based superalloy thick-walled header for cycling and flexible plant operation in new advanced ultrasupercritical (AUSC) and existing ultrasupercritical and supercritical plants. This project focuses on developing a design for the high-temperature nickel-based superalloy header component typical of a thick-walled header subjected to thermal and pressure cycling of full-scale AUSC steam cycle loading conditions. This upfront analytical simulation of the design will eliminate or minimize potential operational problems for the actual ComTest-AUSC and will lead to successful testing of advanced materials for thick-walled pressure parts such as the headers and piping. This project will design the layout for the piping system and identify specific instrumentation needed for component testing of the AUSC steam temperature cycling and data logging system required during operation.

This project aims to develop a wireless integrated gas/temperature microwave acoustic sensor capable of passive operation (no batteries) over the range 350 – 1000 °C in harsh environments relevant to fossil energy technology, with specific applications to coal gasifiers, combustion turbines, solid oxide fuel cells, and advanced boiler systems. The proposed wireless sensor system is based on a surface acoustic wave (SAW) sensor platform that could be used to detect H2, O2, and NOX gases and monitor the gas temperature in the harsh environment. Fully packaged prototype sensors will be designed, fabricated, and tested under gas flows of H2(< 5%), O2, and NOX in laboratory furnaces, and the sensor response characterized for sensitivity, reproducibility, response time, and reversibility over a range of gas temperatures.

The SAW sensors have the advantage of being potentially readily scalable for rapid manufacturing using photo-lithography/metallization fabrication steps, followed by integration of each sensor into a stand-alone wireless harsh environment sensor package. The SAW gas sensor technology will be targeted for demonstration and implementation in a power plant environment.

NETL is partnering with General Electric Company to develop a high-performance, heavy-duty gas turbine wheel that could increase combined cycle turbine efficiency from approximately 62 to 65%. Specifically, the project will screen two different concepts to develop a thick section >1,200 °F-capable material for heavy-duty gas turbine wheels. The processing requirements for these large components, combined with the elevated temperature and stress property requirements, present a unique set of challenges requiring a new approach to alloy design that will be addressed in this project.

Membrane Technology and Research Inc. (MTR), along with the Babcock and Wilcox Company (B&W), will advance the development of MTR’s existing 1 MWe membrane carbon dioxide (CO₂) capture system by integrating the system with B&W’s 0.6 MWe coal-fired research boiler and performing pilot-scale testing of the integrated system. The combined membrane/boiler system recycles CO₂ to the boiler to increase the CO₂ concentration in flue gas, which reduces the cost of subsequent CO₂ capture. The membrane process, developed by MTR, incorporates MTR’s innovative Polaris™ membranes and a countercurrent sweep module design, and can capture 20 tons CO₂ per day at a coal-fired power plant. The small pilot membrane system was successfully field tested in previous projects with real flue gas. Previous testing of B&W’s research boiler with CO₂-laden combustion air was also conducted to evaluate the impact of CO₂ recycle on boiler performance. This project will provide validation of the integrated system to mitigate risks for scale-up. The membrane unit will be modified and installed at B&W’s research facility in Barberton, Ohio. Parametric testing will be conducted using two types of coal to analyze process parameters while monitoring boiler performance and CO₂ capture efficiency.

Geomechanics Technologies, Inc. is assessing the available data from wells in the Ship Shoal block 107 area within the Gulf of Mexico (Figure 1) and reviewing publicly available geological and seismic data to evaluate CO2 storage potential resource. The project is analyzing the Ship Shoal Block 107 in detail by preparing a high resolution 3D geologic model and integrated geomechanical and fluid flow models. The objective of this project is to characterize the Neogene delta sands in the Ship Shoal Area for large scale CO2 sequestration. This is being accomplished through a research program that includes: 1) evaluation of available exploration and development well logs and all available geologic and geophysical data in the public domain; 2) development of 3D geologic models to depict a representation of the subsurface geology to support the prediction of CO2 storage capacity within 30 percent; 3) development of a CO2 injection model to simulate CO2 migration and containment in the Ship Shoal 107 field; 4) development of a 3D geomechanical model to simulate induced stresses and potential fault reactivation due to CO2 injection in the vicinity of typical faulted structures; 5) performing a comprehensive evaluation of storage capacity and seals; and 6) performing a risk assessment and analysis of existing oil and gas infrastructure for CO2 transportation and providing recommendations for a potential transportation pipeline corridor.

This project aims to develop a novel technology for production of high-performance boride-based materials for MHD Direct Power Extraction, which combines the advantages of mechanical activation-assisted self-propagating high-temperature synthesis (MASHS) and pressureless sintering. First, ZrO2/B2O3/Mg and HfO2/B2O3/Mg mixtures will be mechanically activated. NaCl diluent will be added to the mixtures before milling. To determine the mechanisms and kinetics of self-propagating high-temperature synthesis (SHS) reaction, thermoanalytical experiments Thermogravimetric Analysis (TGA) and Differential Scanning Calorimetry (DSC) will be conducted. The mechanically activated powders will then be compacted into pellets and ignited in an argon environment. MgO and Mg will be removed from SHS products by mild acid leaching, while NaCl will be removed by dissolution in water. The milled powders and SHS products will be characterized using X-ray Diffraction (XRD), Scanning Electron Microscopy (SEM), particle size, and surface area analyses. The SHS products will be mixed with dopants, compacted into pellets, and densified using pressureless sintering. Thorough investigation of Thermophysical, electrical, mechanical, and oxidation properties of the obtained materials will be conducted.

As advanced fossil energy systems progress towards higher efficiencies and ultra-low emissions, the conditions under which fuel is converted to power are becoming increasingly harsh (i.e., pressure, temperature, and corrosivity increases), leading to accelerated rates of degradation and failure of materials and components. A reliable and long-term monitoring capability will contribute to the overall reliability of the combustion turbine; however, real-time component condition monitoring in an industrial gas turbine presents significant technical challenges in several key technology development areas. To meet the need for continuous monitoring, Siemens and its key partner Arkansas Power Electronics will develop an innovative, real-time sensor integrated component monitoring concept in the combustion turbine for long-term engine operation.

The objective of the program is to integrate durable, non-intrusive, ultra-high-temperature thermocouples (greater than 1200 °C) with high-temperature wireless telemetry to enable materials prognostics and active condition monitoring in the hot gas path of industrial gas turbines. The specific objectives are (1) to fabricate and install smart turbine blades with thermally sprayed sensors and high-temperature wireless telemetry systems in an H-Class engine, and (2) to integrate the component engine test data with remaining useful life (RUL) models and develop an approach for networking the component RUL data with Siemens’ Power Diagnostics engine monitoring system. Phase 1 involves scaling up the thermal spray process to develop high-temperature ceramic thermocouples with development of wireless telemetry system components, and demonstration of integrated sensor/wireless telemetry approach on stationary lab test rig.

University of Colorado is developing a new technology that can repair wellbore leakage through the electrochemical injection of nanoparticles while simultaneously removing harmful ions out of the wellbore. Wellbore healing agents are being tested and selected based upon their ability to penetrate deep into the leaking areas and better enhance the mechanical and transport properties of well cement (Figure 1). A small-scale laboratory prototype wellbore test system is being developed which extends the electro-migration effect. The effectiveness of the proposed technology is being evaluated through systematic testing of the cementitious materials that are enhanced with the select nanoparticles. Finally, a multiphysics numerical model is being developed to simulate the remediation process utilizing this new technology.

American Air Liquide Inc. (AL), in partnership with Parsons Corporation, will continue the development and advanced testing of a novel polyimide-based membrane material (PI-2) for application in AL’s hybrid process for carbon dioxide (CO2) capture from coal-fired flue gas. The process combines cold membrane operation with an integrated CO2 compression and purification unit to significantly reduce the overall cost of capture. This project builds on preceding bench-scale work (DE-FE0004278) in which commercial AL hollow-fiber membranes (PI-1), operated at temperatures below -20°C, were shown to have 2-4 times higher CO2/(nitrogen) N2 selectivity with comparable CO2 permeance as ambient temperature performance. In a follow-on project (DE-FE0013163) bench-scale testing on actual flue gas gave promising results for the hybrid process using the existing commercial AL membrane bundles (PI-1 material), and initial laboratory testing of the novel membrane material (PI-2) showed the potential for a step-change in performance (greater than 5 times the fiber permeance of PI-1). The main focus of the current project is to advance the novel high CO2 permeance PI-2 membrane material to commercial-scale 6” bundles for testing with actual flue gas in a 0.3 MWe test unit at the National Carbon Capture Center. A comprehensive evaluation of the overall hybrid process and costs will be completed to ensure optimal use of the improved material and to benchmark against other CO2 capture technologies.

This University of Notre Dame, in collaboration with Lawrence Livermore National Laboratory (LLNL), will test the use of hybrid encapsulated ionic liquid (IL) and/or phase change ionic liquid (PCIL) materials for post-combustion carbon dioxide (CO₂) capture. Promising ILs and/or PCILs have proved to be prohibitively viscous for large scale commercial operation when configured in conventional absorption/regeneration systems. Encapsulated ILs and PCILs have high surface areas, allowing researchers to break through the mass transfer barriers caused by high viscosities. The team will combine the advantages of two recently proven technologies—Notre Dame’s IL and PCIL materials with high capacity and low regeneration energy, and LLNL’s microencapsulation in polymer shells—to make and test high surface area materials specifically engineered for high-efficiency CO₂ capture from post-combustion flue gas. The expected outcome of this project will be successful synthesis of the microencapsulated ILs and/or PCILs and validated CO₂ removal from simulated flue gas in a laboratory-scale unit with dramatically improved mass transfer.

The University of South Carolina will develop accelerated test protocols based on recent preliminary results and theoretical analyses to establish common approaches for determining and projecting the durability of solid oxide fuel cell (SOFC) cathodes under simulated operation conditions. In addition, researchers will tune the microstructures of lanthanum strontium cobalt iron oxide (LSCF) and nickelates to simultaneously obtain high-power density and high-performance stability. Developing accelerated test protocols remains a challenge because operating SOFCs under normal conditions for tens of thousands hours is often costly and impractical. Therefore, accelerated tests are needed to facilitate rapid understanding of key durability and reliability issues. This project leverages research from a previous DOE contract, DE-FE0023475.

MicroBio Engineering, Inc. has teamed with Orlando Utilities Commission Stanton Energy Center (OUC-SEC), University of Florida–Gainesville, Arizona State University, Scripps Institution of Oceanography, Life Cycle Associates LLC, and SFA Pacific, Inc. to investigate power plant integration with microalgal production systems for the production of bulk commodities to beneficially utilize and mitigate carbon dioxide (CO2) emissions from coal-fired power plant flue gas. Techno-economic analyses, lifecycle assessments, engineering studies, and experimental work will be conducted for the site-specific case of utilization of flue gas from the OUC-SEC 800 MWe coal-fired power plant in Florida, sunlight, and local water sources to cultivate algal strains for production of biogas and animal feeds. Bench-scale experimental work at both OUC-SEC and the University of Florida will be conducted to test the growth of native microalgae under local conditions with actual CO2-laden flue gas and pure CO2. Project researchers will investigate two cases for CO2 mitigation and beneficial utilization: (1) biogas production from microalgal biomass and (2) production of bulk commodity premium microalgae animal feed to maximize the beneficial use of flue gas CO2. The microalgae cultivation process is based on an existing technology using large raceway ponds with projected algae productivity of nearly 50 metric tons of ash-free dry weight biomass per hectare per year. The anticipated results are detailed projections of the potential for and limitations of using microalgae for CO2 mitigation and beneficial utilization at the OUC-SEC coal-fired power plant. A technology gap analysis will be conducted on increasing microalgae productivity and optimizing market-driven sale of bulk feed commodities to help offset CO2 mitigation costs.

The team of Southwest Research Institute® (SwRI®) and Thar Energy LLC (Thar) will evaluate indirect fossil based supercritical carbon dioxide (SCO2) power plants via system engineering design and thermodynamic analysis of integrated power plants. This evaluation will be used to assess the impact of thermal integration on plant performance and identify current technology gaps when integrating fossil based thermal systems with SCO2 power blocks. This will extend our current understanding of how fossil based thermal systems may best be integrated with recuperated closed Brayton cycles and identify component and boiler technology requirements and integration issues for future development and risk reduction. The project team will also evaluate a novel absorption/desorption based SCO2 power cycle that utilizes an absorption/desorption circuit to minimize compression work. Physical properties testing of suitable binary fluid mixtures at pressures and temperatures of interest for SCO2 power cycles will facilitate the system engineering design and thermodynamic analysis of the SCO2 absorption/desorption cycle. This work builds on DOE contracts FE0024104 and FE0024012 to advance fossil based utility scale SCO2 power plants by addressing integrated SCO2 plant efficiency, cost, and operating characteristics.

TDA Research, Inc. (TDA), in collaboration with the University of California – Irvine, the University of Alberta, and the Gas Technology Institute, will develop a new chemical absorbent-based air separation process that can deliver low-cost oxygen to integrated gasification combined cycle power plants. The specific objectives of the work are to increase the technical maturity and commercial viability of the new absorbent-based air separation technology by (1) demonstrating continuous oxygen generation in a prototype test system and (2) carrying out a high fidelity process design and economic analysis. The TDA prototype unit will consist of three fixed-bed reactors, which can generate a minimum of 1 kg/hour of oxygen on a continuous basis. The system will be capable of stand-alone operation, treating up to 12 normal cubic meter per hour air at different inlet pressures. In a series of tests, the research team will validate the results from the absorption model and computational fluid dynamics simulations and conduct multiple-cycle tests under optimum operating conditions, delivering a high purity oxygen product. This project leverages research from previous DOE contracts DE-FG02-05ER84216, DE-FG02-07ER84677, and DE-FE0024060.

This work involves the exploration of design and prototyping of a Dry Low-NOx (DLN) fuel injector with integrated temperature sensing capabilities using the electron beam melting (EBM) additive manufacturing (AM) process. Low-NOx natural gas fuel injectors, commonly used in Dry Low NOx (DLN) gas turbine combustors, have complex internal cavities and passages to ensure tailored mixing of air and fuel to achieve ultra-low levels of NOx emissions. Since the current design methodology of these injectors is based on conventional fabrication techniques (e.g., multi-step machining and welding processes), a new paradigm of design methodology needs to be developed for their adaptation to the EBM fabrication process.

The proposed effort has three specific objectives: (1) development of design methodologies for Low-NOx fuel injectors with embedded temperature capabilities for EBM based 3D Manufacturing; (2) development of optimum EBM process parameters and powder removal techniques to remove sintered powder from internal cavities and channels of Low-NOx fuel injectors with embedded temperature sensors; and (3) testing of the EBM fabricated Low-NOx fuel injector with integrated temperature measurement capabilities in a High Pressure Laboratory turbine combustor.

Southern Research, along with IntraMicron and Nexant, will conduct laboratory-scale research to develop a combined magnesium oxide (MgO)-based carbon dioxide (CO₂) sorbent/water-gas shift (WGS) reactor that offers the simplicity of a fixed-bed adsorber/reactor and also the reactivity and heat management ability of a complex fluidized bed reactor. In addition to consolidating CO₂ capture with WGS, the process will reduce parasitic energy losses by operating at warm gas temperatures, reduce parasitic plant load (i.e., steam and auxiliary power) by reducing or eliminating temperature swings for regeneration, and reduce separation costs by regenerating the sorbent in a stream of 99 percent CO₂. The heat management capability is based on IntraMicron’s microfibrous entrapped catalyst (MFEC) technology. The project goal is to develop a combined CO₂ sorbent/WGS reactor-based process with advanced integrated heat management to capture 90 percent of the CO₂ from the Transport Reactor Integrated Gasifier (TRIG) syngas for integrated gasification combined cycle (IGCC) applications. The process will also be applicable to other gasifiers that are candidates for IGCC power plants with CO₂ capture, and aims to reduce the cost of electricity by 30 percent as compared to conventional CO₂ capture methods. Project researchers will develop the CO₂ sorbent/WGS catalyst reactor system through rigorous modeling and laboratory-scale testing, with the goal of being ready for potential subsequent bench-scale testing by the end of the project.

Arizona State University, in collaboration with Media and Processes Technology Inc., the University of Cincinnati, Nexant Inc., and the University of Kentucky, will develop a bench-scale zeolite membrane reactor for water-gas shift (WGS) reaction with carbon dioxide (CO₂) capture. The project is based on the previous successful lab-scale validation of a stable, hydrogen (H2) semi-permeable MFI-type zeolite membrane reactor. The research includes scaling-up the synthesis of zeolite membrane tubes; design and fabrication of the membrane reactor modules; testing bench-scale zeolite membrane reactors; and process design and techno-economic analysis of the membrane reactor for integrated gasification combined cycle (IGCC) applications. Once developed, the bench-scale zeolite membrane WGS reactor will be tested using raw synthesis gas (syngas) from a coal gasifier for H2 production at a capacity equivalent to a 2 kWth IGCC power plant. The project goal is to develop a bench-scale zeolite membrane reactor with the capacity of producing 2 kg of H2 per day, and to identify the operating conditions for a single-stage membrane reactor to produce a concentrated H2 stream with carbon monoxide conversion higher than 99 percent, CO₂ capture greater than 90 percent, CO₂ purity greater than 95 percent, and a cost of CO₂ capture at less than $40/tonne of CO₂. The performance and cost-effectiveness of the membrane reactor process will be evaluated for use in a 550-MWe coal-burning IGCC plant for CO₂ capture.

Research Triangle Institute (RTI) International has teamed with Linde, LLC, and SINTEF Petroleum Research to continue the advancement of RTI’s water-lean solvent-based carbon dioxide (CO₂) capture process by testing it at up to 60-kW benchscale using actual coal-derived flue gas and validating its potential to reduce the parasitic energy penalty associated with the capture of CO₂ from flue gas. The water-lean solvent will be tested, using coal-fired flue gas, at both SINTEF’s pilot plant facility (Tiller Plant) and at the National Carbon Capture Center’s Slipstream Solvent Test Unit. The largest energy demand in state-of-the-art solvent-based CO₂ capture processes comes from regenerating the solvent to remove the captured CO₂. RTI’s water-lean solvent technology was previously proven, using simulated flue gas at a smaller scale, to have low-regneration temperatures, allowing use of lower-quality steam. The project objectives are to validate the process using coal-derived flue gas, test the process at a significantly larger scale at the Tiller Plant, and finalize the solvent chemistry to further increase hydrophobicity that will simplify and enhance the process operation. Data obtained from testing will be used to perform a techno-economic analysis, the results of which will determine the potential for the water-lean solvent-based CO₂ capture process to achieve the U.S. Department of Energy’s (DOE) technical and CO₂ capture cost targets.

The project aims to develop and demonstrate a data integration, assimilation, and learning framework for geologic carbon sequestration projects (DIAL-GCS). DIAL-GCS is an intelligent monitoring system (IMS) for automating GCS closed-loop management. It leverages recent advances in computer programming. Specifically, the project is developing an ontology-driven GCS data management module for storing, querying, and exchanging GCS data (both historic and live sensor data) from multiple heterogeneous formatted sources. It incorporates a complex-event processing engine for detecting abnormal situations. This engine is being developed by combining expert knowledge, rule based reasoning, and machine learning. The IMS is being designed to enable uncertainty quantification and predictive analytics using reduced-order modeling. The IMS capabilities are being integrated and developed with both real and simulated data from the Cranfield, Mississippi carbon storage test site.

The Energy & Environmental Research Center (EERC) at the University of North Dakota is developing new, real-time-datacapable workflows designed to automate the integration of carbon dioxide (CO2) storage site monitoring data within an intelligent monitoring system (IMS). The algorithms and workflows developed are capable of handling both periodic and real-time data. Compared with traditional manual processing, interpretation, and integration workflows, the software allows a CO2 storage site operator to more efficiently monitor and manage a site’s evolving risk profile. If incorporated into an active reservoir management control system, the software will allow for definition of risk trigger points based on user-defined criteria. These triggers can hence be used to automate field operations, such as flow rates within specified injection zones to optimize storage performance and efficiency and/or reduce the project’s risk profile while simultaneously minimizing human error and operational response times. This is being accomplished by integrating continuous monitoring data (such as pressure, temperature, and injection rate measurements), periodic monitoring data (such as seismic data, well logs, gravity surveys, and near-surface monitoring data), and reservoir performance simulations (which have been improved with monitoring data) with software algorithms linked to a technical user interface for visualization and real-time decision-making support.

The project will systematically evaluate the potential to deploy targeted carbonation reactions to the leading edge of leaking CO2 as a strategy for mitigating leakage from deep CO2 injection sites. This project focuses on the development of stimuli-responsive coated mineral silicates that can be used in the targeted treatment and remediation of leaking CO2 in geologic storage sites and wellbores (Figure 1). This self-targeted approach eliminates the need for leaks to be precisely located before they can be mitigated, thus improving confidence in containment. Specifically, this project will synthesize coated mineral silicates and evaluate their ability to mitigate leakage experimentally and with forward modeling.

The University at Buffalo has teamed with Membrane Technology and Research, Inc. and Helios-NRG, LLC, to develop a membrane-based process to capture carbon dioxide (CO₂) from coal-derived syngas with less than 10 percent increase in the levelized cost of electricity. The key advancement of this technology is a series of novel sorption enhanced mixed matrix membranes with high hydrogen (H₂) permeance (500 GPU) and high H₂/CO₂ selectivity (30) at temperatures up to 200°C. The approach combines highly cross-linked polymers with strong size sieving ability and palladium-based nanomaterials with high H₂/CO₂ selectivity to achieve membranes with performance superior to stand-alone polymeric membranes. The project team will fabricate and optimize thin film composite membranes, perform parametric testing using simulated syngas in the laboratory, and conduct field testing of the membrane stamps at the University of Kentucky Center for Applied Energy Research with actual syngas. A process design and a techno-economic analysis will be completed based on the newly developed membranes. This analysis will clarify the potential of membrane technology for CO₂ capture from coal-derived syngas, providing the criteria of membrane performance that must be met to achieve the DOE program goals.

Liquid Ion Solutions LLC, in partnership with Penn State University and Carbon Capture Scientific, will develop and validate a transformational hybrid membrane/solvent system for post-combustion carbon dioxide (CO²) capture from flue gas. The project will build on work previously conducted by Liquid Ion Solutions in mixed-matrix membrane (MMM) development, Penn State in polymer synthesis and property optimization, and Carbon Capture Scientific in solvent systems. The hybrid technology is a two-stage CO² capture system combining a membrane separation process and an absorption/stripping process with heat integration between the absorption column and stripping column through a heat pump cycle. Process air is used to sweep the stripper resulting in much lower regeneration temperatures and enabling heat integration to the point that no process steam is required. To reduce capital cost, a next-generation membrane technology with higher permeance will be developed. The interfacially-controlled envelope (ICE) membrane will make use of a transport zone neglected in conventional MMMs. By carefully controlling the interface between the polymer and inorganic particles within the MMM, CO² transport will be encouraged and nitrogen transport diminished in the gap between the two phases. Since permeance is directly tied to membrane area and capital cost, the development of the ICE membranes will reduce the capital cost of the hybrid process below that of the baseline technologies. The research team will combine computer simulation with lab-scale experimentation using simulated flue gas to develop, optimize, and test ICE membranes, test the absorption column and air stripper, and complete a techno-economic analysis of the hybrid technology.

The objective of this research project was to develop and validate a program for identifying and characterizing wellbore leakage for carbon dioxide (CO2) storage applications based on analytics of well records validated with sustained casing pressure field monitoring. Major objectives included determining the nature of well defects, location of defects within the borehole, and severity of the leakage rate associated with that defect (Figure 1). This project surveyed wells in the Michigan, Appalachian, and Williston basins. The field-testing results did not show significant well defects. Project results were used with geochemical analysis to identify trends that lead to better understanding and prediction of well integrity issues for CO2 storage applications.

FuelCell Energy, Inc. (FCE) and its wholly owned subsidiary, Versa Power Systems, will collaborate with University of Connecticut and Sonata, LLC to develop a breakthrough portfolio of technologies to produce solid oxide fuel cell (SOFC) stacks and systems at costs below DOE targets and provide a cost competitive edge over existing technologies. The FCE team will develop a low-cost method of manufacturing the anode support layer by reducing the sintering temperature to less than 1300°C. The team will also investigate advanced manufacturing of the cell components and explore a technique to reduce the thickness of the barrier layer and decrease imperfections. The team will develop an innovative stack technology with two-pass flow geometry for better thermal management, material reduction, better packaging within stack modules, and ease of installation. The FCE team will design and fabricate a nominal 5 kilowatt-scale stack using full-size cells for testing for at least 1000 hours at normal operating conditions and prepare cost estimates for SOFC cell and stack technologies developed during this project based on high volume manufacturing techniques. The project will build on previous DOE funded work, most recently DE-FE0023186.

FuelCell Energy, Inc. (FCE) and its subsidiary, Versa Power Systems, will design, fabricate, and test a state-of-the-art 400 kilowatt (kW) prototype system comprised of two thermally self-sustaining atmospheric-pressure 200 kW Solid Oxide Fuel Cell (SOFC) power generators to be installed and operated at a prominent site. This work will demonstrate SOFC stack reliability and endurance and utilize FCE’s SOFC system design philosophy based on factory-assembled stack building blocks, which may be used to fabricate larger multi-stack modules for both sub-megawatt (MW) and multi-MW systems applications. Ultimately, thirty-two baseline 120-cell SOFC stack blocks will be fabricated and integrated into four 100 kW modular power blocks (MPBs) for the 400 kW prototype system. The system design will include novel balance of plant (BOP) components and operational/control strategies to improve SOFC stack endurance and reliability. The system testing will serve to validate key design features of the MPB (e.g., SOFC stack arrays and towers, and integration of hot BOP components), which are enabling technologies for larger-scale MW-class stack modules.

NETL is partnering with Florida International University to develop nanocarbide and boride ceramic solid solution and related composites via novel synthesis and processing and to understand the fundamental composition processing-structure-property relationships for materials candidates for applications such as hot electrodes for direct power extraction, e.g., magnetic hydrodynamic (MHD) systems. Basic research on new high-temperature ceramic materials, including novel means of synthesis and processing, will be performed. Fundamental knowledge will be developed and leveraged to design direct power extraction applications for cleaner and more efficient power generation using fossil fuels.

NRG Energy, Inc. (NRG) researchers, in partnership with Inventys, are working to establish the technical feasibility and economic viability of Inventys’ VeloxoThermTM post-combustion carbon dioxide (CO2) capture process. VeloxoTherm is an intensified temperature swing adsorption process that uses a patented architecture of structured sorbent and process design to economically capture CO2 from industrial flue gas streams.Previously validated for CO2 capture from natural gas, the project will progress the technology for testing on a 10 MWe equivalent, or greater, coal-fired flue gas slipstream and address associated contaminants and process integration. Process testing completed previously was performed with the intent to de-risk the technology for multiple applications, including coal. During Phase I, NRG will determine the scope, configuration, and design basis of the system; determine optimal size and host site location on one of NRG’s coal plants; complete techno-economic and technical gap analyses; and update the project management plan. The VeloxoTherm process presents a number of process integration opportunities, including the source of process steam, auxiliary power, and plant utilities, which will be considered in the evaluation of alternative NRG host sites and plant scales.
Projects for the large-scale (equivalent of 10 to 25 MWe) pilot testing of post-combustion CO2 capture technology systems are being conducted in two phases, with a competitive downselect to continue from Phase I into Phase II. This project was selected for Phase I; a Phase II application must be submitted to be considered for the full project.

Acumentrics SOFC Corp. (Acumentrics) and Boston University (BU) are working to support an industry goal to rate fuel cells at constant performance for more than 40,000 hours (the target duration required for widespread acceptance of fuel cells in the power generation market). A problem facing developers is the lack of an accepted method to accelerate solid oxide fuel cell (SOFC) degradation in the laboratory in order to accurately predict long-term degradation in the field. The objective of this work is to perform an in-depth analysis of stack degradation in SOFCs that have been in actual service (aged) from 1,000 to 25,000 or more hours. The work will focus on tubular stacks commercialized by Acumentrics. Project personnel will conduct a detailed spatial electrochemical characterization of aged SOFCs and a detailed spatial material characterization of tubular SOFCs using modern diagnostic tools. These data will be organized along with stack metadata (operating parameters, time, and geometrical position) into a database to correlate degradation data with the metadata in order to isolate patterns of degradation.

Gas Technology Institute has teamed with the University of South Carolina, Porogen Corporation, and Trimeric Corporation to develop a hybrid process for capturing carbon dioxide (CO2) from the flue gas of pulverized coal-fired power plants. The process will combine a conventional gas separation membrane unit and a solvent-based capture process that utilizes a novel hollow fiber membrane contactor unit to capture greater than 90 percent of the carbon dioxide (CO2) with 95 percent CO2 purity at a cost of electricity 30 percent less than the baseline CO2 capture approach. The hybrid process integrates the ultrathin graphene oxide (GO) membrane process with the polyether ether ketone (PEEK) hollow fiber membrane contactor (HFMC) process for increased reduction in the cost of CO2 capture. The GO membranes will capture the bulk of the CO2 from coal-fired flue gas and the PEEK HFMC unit will capture additional CO2 to achieve DOE’s performance targets. In this project, the GO membrane preparation method will be optimized to achieve membranes with CO2/N2 selectivity of greater than 90 and a CO2 permeance of at least 1,000 GPU. Third-generation PEEK fibers will be optimized and manufactured with an intrinsic permeance of at least 3,000 GPU. The GO membrane unit will be integrated with the PEEK membrane contactor unit to measure the system performance. Testing of the bench-scale integrated GO-PEEK hybrid system will be conducted with simulated flue gas. A techno-economic feasibility study will be completed based on the integrated testing data.

The University of Kentucky (UK) has teamed with the University of Delaware College of Earth, Ocean, and Environment (UD-CEOE) and ALGIX LLC to develop a cost-effective, biological carbon dioxide (CO2) conversion process that can convert CO2 from coal-fired flue gas to value-added products. The research team will focus on microalgae-based CO2 capture with conversion of the resulting algal biomass to fuels and bioplastics. Scenedesmus acutus algae will be autotrophically cultured in an innovative cyclic flow photobioreactor. The algae will be harvested and dewatered using previously developed UK technology based on flocculation, sedimentation, and filtration. Engineering- and biology-based approaches will be employed to decrease costs, while a sustainable utilization strategy will be developed for the algal biomass produced. The project will specifically address three main areas: (1) critical commercial-scale development barriers such as flue gas introduction, dewatering, and culture maintenance; (2) development of large-scale applications for the produced biomass while maximizing the potential revenue stream; and (3) assessment of the economics and greenhouse gas implications of this approach to CO2 capture and recycle. The project objectives are to optimize UK’s current technology, particularly with regard to harvesting and dewatering operations; develop strategies to monitor and maintain algae culture health; and develop a biomass utilization strategy which simultaneously produces lipid feedstock for direct upgrading to fuels and a proteinaceous feedstock for the production of algal-based bioplastics, thereby maximizing the value of the algal biomass. Techno-economic analyses to calculate the cost of CO2 capture and recycle using this approach, and life cycle analyses to evaluate the greenhouse gas emission reduction potential will be completed.

The University of Kentucky’s (UK) Center for Applied Energy Research (CAER) has teamed with Electric Power Research Institute (EPRI) to further develop its heat-integrated, post-combustion carbon dioxide (CO2) capture system for application on a coal-fired power plant. The goal of this project is to scale up and test, at 10 MWe, the CAER system that uses heat integration, two-stage stripping, and an advanced solvent to enhance the CO2 absorber performance, thereby improving plant efficiency. The project will be modeled directly after CAER’s small pilot (0.7 MWe) CO2 capture system located at the Louisville Gas and Electric Company (LG and E) and Kentucky Utilities Company (KU) E.W. Brown power plant. Two key aspects that differentiate the technology from other capture systems are (1) a two-stage stripping unit for solvent regeneration in which the second stage air-stripper is empowered by the heat rejection from the first stage conventional steam-heated stripper, thereby reducing the energy penalty, and (2) a heat-integrated cooling tower system that recovers waste energy from the carbon capture system. Phase I tasks include developing the preliminary engineering design, techno-economic analysis, and technology gap analysis; incorporating small pilot (0.7 MWe) data; selecting a host site; and defining the Phase II experimental design. Projects for the large-scale (equivalent of 10 to 25 MWe) pilot testing of post-combustion CO2 capture technology systems are being conducted in two phases, with a competitive downselect to continue from Phase I into Phase II.

This project was selected for Phase I; a Phase II application must be submitted to be considered for the full project.

NITEC, LLC is developing a high level quantitative assessment of the CO2 volume that can be stored in depleted oil and natural gas fields in the offshore federal waters of the Gulf of Mexico (GOM) on a field by field basis. This project is establishing a ranked list of fields based on prospective CO2 sequestration volume. This enables future, more detailed studies to focus on specific fields based on their size, location and currently available public data. Accordingly, it is highlighting areas of the offshore GOM where there are deficiencies in candidate fields for CO2 storage either due to size, lack of data, or oil and natural gas remaining depletion life. The project is estimating individual field storage resource using DOE developed volumetric equations. This use of these equations require assessment of the in-situ hydrocarbon fluid volumes for the field under evaluation. This project is utilizing public data from the U.S. Department of the Interior, Bureau of Ocean Energy Management (BOEM) reserves database5, and from a well reputed, large database (250,000+ wells) of GOM well and production data marketed by IHS, Inc. The databases will be used along with geological and petrophysical software (Petra) to identify depleted oil and gas fields in the Federal GOM region.

Texas A&M University has teamed with framergy™ to develop and test amine-incorporated porous polymer networks (aPPNs) for low-energy selective capture of carbon dioxide (CO₂) from flue gas. aPPNs are novel porous sorbents that exhibit exceptional gas uptake capacities and working capacities, with the added capability of fine tuning the CO₂ selectivity through the incorporation of amine groups. These innovative materials will address many of the limiting factors in both solvent and other sorbent-based CO₂ capture methods, mainly the energy required to regenerate the post-combustion CO₂ capture system. The project objectives are to optimize the sorbent and process technologies to develop a scalable, highly-robust, and highly-efficient sorbent, and validate the sorbent through lab-scale, fixed-bed testing with simulated flue gas. The goal at the end of this lab-scale evaluation is to collect all the relevant data and overcome the challenges for scaling-up the best performing sorbent for future bench-scale testing in a fluidized-bed system.

Oregon State University (OSU) will develop and evaluate a pulse detonation combustion system for direct power extraction. The system will work on either gaseous (e.g., natural gas) or solid (e.g., coal) fuels. OSU will computationally investigate coupling the pulse detonation combustor with a magnetohydrodynamics (MHD) system. Such a system can be used as a topping cycle to improve the efficiencies of industrial power plants. Specific objectives of this effort include (1) design, build, and operate a pulse detonation engine that operates on gaseous or solid fuels with air and oxygen as the oxidizer; (2) evaluate the operational envelope and performance of the pulse detonation engine; and (3) develop and validate a numerical design tool to calculate the performance of both pulse detonation and coupled detonation-MHD systems. Methane with other gaseous fuels will be considered initially to provide validation data for the detonation model, gain confidence in the combustor, and avoid the complexities associated with seeding the flow with coal. Once confidence has been gained in the methane/oxygen combustor, the system will be expanded to operation with coal. A baseline design for a functioning pulse detonation engine will be provided by Innovative Scientific Solutions Inc. at no cost.

The Electric Power Research Institute (EPRI) and a team of five subcontractors (Alstom Power Inc., Babcock & Wilcox Power Generation Group, Inc., Doosan America ATS, Echogen Power Systems, LLC, and Howden Group Ltd.) will develop process designs for test cases that optimally integrate candidate closed Brayton power cycles using supercritical carbon dioxide (SCO2) as the working fluid with oxy/coal-fired SCO2 heaters for comparison with relevant DOE/NETL baseline cases employing steam-Rankine power cycles, and identify technology gaps in the SCO2 Brayton power cycle plants. The team will also develop cost estimates for the SCO2 Brayton cycle power plants coupled with oxy/coal-fired systems for comparison with relevant baseline-case capital costs and associated cost of electricity and identify components whose cost might be reduced by focused R&D.

Georgia Tech Research Corporation has teamed with Inmondo Tech, Inc., to test a novel process that achieves 10 moles per kilogram sorbent swing capacity in a rapidly cycled pressure swing adsorption (RCPSA) process for post-combustion carbon dioxide (CO₂) capture from coal-fired power plants. Novel polymer/metal-organic framework (MOF) sorbent composite hollow fibers will be used in a new sub-ambient RCPSA process that integrates flue gas conditioning with a highly-compact pressure swing adsorption system. The research team will develop, fabricate, and test prototype MOF composite-fiber sorbent modules at sub-ambient conditions. The modules are comprised of polymeric fibers with embedded metal-organic framework particles. This approach benefits from two main innovations: (1) the sub-ambient flue gas is processed with energy and power recovery, enabling a low pressure drop fiber sorbent-based RCPSA system that is extremely compact and (2) a hollow fiber sorbent with a bore-side barrier layer has the potential to make the RCPSA fiber sorbent module even more compact. Additionally, the efficiency of the pressure swing cycle will be boosted by installing a stationary phase-change material in the bores of the hollow fiber sorbents that will isothermally melt upon release of sorption enthalpy and conversely isothermally freeze upon CO₂ desorption, requiring no steam or cooling water. The project is anticipated to result in a lab-scale evaluation of a prototype fiber sorbent module in a sub-ambient RCPSA with simulated flue gas and preliminary design, optimization, and economic analysis of a full scale system.

NETL is partnering with Energy Industries of Ohio Inc. to bring advanced ultrasupercritical (AUSC) technology to the commercial-scale demonstration level of technology readiness by designing a test facility that consists of prototype-scale (approximately 120,000 lbs/hr steam flowrate) equipment components that would operate at AUSC steam temperature up to 760 degrees Celsius (°C) (400 degrees Fahrenheit [°F]) and pressure of 70 bar (1000 pounds per square inch absolute [psia]) or higher; and completing the manufacturing research and development of AUSC components by fabricating commercial-scale nickel superalloy components and sub-assemblies that would be needed in a coal-fired power plant of approximately 800 megawatts generation capacity (MWe) operating at a steam temperature of 760 °C (1400 °F) and steam pressure of at least 238 bar (3500 psia).

Thar Energy LLC (Thar) will lead a technology development program with partner Southwest Research Institute (SwRI) and subcontractors Oak Ridge National Laboratory (ORNL) and Georgia Institute of Technology (material characterization and corrosion expertise) to advance high-temperature, high-differential-pressure recuperator technologies suitable for use in the supercritical carbon dioxide (SCO2) recompression Brayton cycle (RCBC). The focus of the development program is to evaluate, advance, and demonstrate recuperator concepts, materials, and fabrication methods that facilitate the commercial availability of compact, low cost recuperators for use under RCBC conditions greater than 700°C and differential pressures of approximately 200 bar. Researchers will consider variations of the microtubular design to address operability, inspection, maintenance, scalability, manufacturability, and cost. The technology development program is structured to (1) evaluate the novel recuperator concepts using engineering analysis for comparison with the current state of the art; (2) advance promising concepts through initial design and down selection; (3) complete the detailed design of the selected concept; and (4) fabricate a 46.6 MW (thermal) recuperator to accommodate the 10 MW (electric) SCO2 Supercritical Transformational Electric Power (STEP) demonstration. This work builds on previous DOE contracts DE-EE0005804 and DE-FE0024012.

Research Triangle Institute (RTI) will develop novel third-generation fluidizable solid sorbents for their sorbent-based carbon dioxide (CO₂) capture process. Two novel sorbent approaches, based on hybrid-metal organic frameworks (MOFs) and hybrid-phosphorus (P)-dendrimers, have been identified with promise to achieve DOE’s performance and cost goals. The primary project goal is to design and synthesize several novel hybrid-based MOF and P-dendrimers with enhanced stability and higher CO₂ capacity, then thoroughly evaluate and show their potential to further drive down the cost of CO₂ capture. From this group, the most cost-effective sorbent that can meet DOE’s goals will be selected. RTI researchers will conduct lab-scale testing in RTI's packed-bed reactor and fluidized, moving-bed reactor with simulated flue gas; evaluate the sorbents’ stability and the impact of contaminants, temperature, and humidity; and complete high-level technical and economic analyses to understand the potential of these sorbents to substantially reduce the cost associated with CO₂ capture from coal-fired power plants. The project is designed to explore the promise of novel solid CO₂ sorbents to further lower the cost of CO₂ capture, establish an understanding of how process elements influence CO₂ capture performance, and provide information for a technology feasibility study, which will prove the commercial potential of a hybrid solid sorbent-based CO₂ capture technology.

General Electric (GE) will further develop its aminosilicone carbon dioxide (CO2) capture system in partnership with the Technology Centre Mongstad (TCM). The aminosilicone technology is a non-aqueous chemical solvent that GE has developed in collaboration with the U.S. Department of Energy (DOE), beginning with laboratory experimentation and material screening in 2008. Based on bench-scale test results, the aminosilicone technology offers a CO2 capture cost of $46/tonne CO2. This cost potential is being tested at the small pilot scale (0.5 MWe) under a predecessor project at the National Carbon Capture Center. The small pilot test results will be used to develop a 10 MWe project plan. The primary test objective is to complete two months of continuous operation to validate performance claims and de-risk the technology. During the test protocol, GE will conduct experiments to observe the performance and flexibility of the aminosilicone system under conditions of reduced steam temperature (opportunity heat sources) and reduced steam flow rate (power island partial load). GE proposes to utilize the TCM as the host site. In Phase I, GE will develop a plan to define the large pilot-scale project, and minimize and quantify risks associated with technical success, cost, and schedule. Tasks will include a technology gap analysis; a screening-level design and cost estimate; an environmental, health, and safety assessment report; and a techno-economic analysis for the CO2 capture system. The information will be compiled and integrated into an experimental design, budget, and schedule for the Phase II pilot test project.
Projects for the large-scale (equivalent of 10 to 25 MWe) pilot testing of post-combustion CO2 capture technology systems are being conducted in two phases, with a competitive downselect to continue from Phase I into Phase II. This project was selected for Phase I; a Phase II application must be submitted to be considered for the full project.

Archer Daniels Midland Corporation (ADM) is developing an integrated intelligent monitoring system (IMS) architecture that utilizes a permanent, continuously active surface seismic monitoring network for process surveillance and optimization. Specifically, this project aims to use a continuously active seismic source monitoring system, in addition to downhole temperature and pressure data, and modeling to monitor, track, and optimize the injection of carbon dioxide (CO₂) into the Mt. Simon saline reservoir. The project is being carried out at ADM's Decatur, Illinois site in conjunction with the Illinois Industrial Carbon Capture and Storage Project (Figure 1).

Alstom Power Inc. (Alstom) has teamed with Technology Centre Mongstad (TCM), the Georgia Institute of Technology, General Electric Power and Water, Purecowater, and ElectroSep Inc. to improve Alstom’s Chilled Ammonia Process (CAP) carbon dioxide (CO2) capture technology using commercially-available membrane technologies to reduce energy and capital costs. Concepts incorporating liquid-liquid reverse osmosis and bipolar electrodialysis membrane technologies will be tested at an existing 15 MWe CAP facility at TCM. Alstom will utilize previous bench-scale results to properly select the membrane technologies. Phase I project objectives are to complete preliminary design and economic analyses for the test program, including four membrane concepts; develop the cost estimate and schedule to modify the existing large-pilot facility at TCM; and complete preliminary techno-economic and technology gap analyses for the CAP technology at the 550-MWe scale.
Projects for the large-scale (equivalent of 10 to 25 MWe) pilot testing of post-combustion CO2 capture technology systems are being conducted in two phases, with a competitive downselect to continue from Phase I into Phase II. This project was selected for Phase I; a Phase II application must be submitted to be considered for the full project.

GE Global Research, in partnership with GE–Fuel Cells, LLC and West Virginia University (WVU) will develop a thermal-spray, redox stable, ceramic anode that will enable robust, large scale, metal supported solid oxide fuel cells (SOFCs). The overall program objective is to define an optimized ceramic anode chemistry, and its thermal spray processing conditions, to enable scalable, low-cost, manufacturing utilizing GE’s extensive thermal spray network. Researchers will assess a single, simple redox stable anode composition: lanthanum doped strontium titanate combined with doped cerium oxide. Thermal spray manufacturing of a ceramic anode on a metal supported substrate will be demonstrated and material property requirements established. Sub-micron/micron sized powders with optimized composition and material properties will be produced for use in thermal spray manufacturing. GE Global Research will tailor the thermal spray process and engineer the powder microstructure to produce high performing SOFC cells. WVU will develop and down-select high performing ceramic anode chemistries that are amenable to the thermal spray process. Finally, GE–Fuel Cells will assemble, instrument, and operate a 5 kilowatt stack at its test lab for at least 1000 hours on natural gas or simulated natural gas fuel.

FuelCell Energy, Inc. (FCE) is partnering with AECOM Technical Services to continue development of its novel system for separation of carbon dioxide (CO2) from greenhouse gas emission sources using FCE’s patented Combined Electric Power and Carbon Dioxide Separation (CEPACS) system. The CEPACS system is based on an electrochemical membrane (ECM) technology. The driving force for CO2 separation is electrochemical potential and results in simultaneous power production and CO2 separation. The membrane consists of ceramic-based layers filled with carbonate salts, and separates CO2 from the flue gas with a selectivity of 100 percent over the nitrogen present in the gas. Because of fast electrode kinetics, the low CO2 concentration normally found in PC plant flue gas is suitable for ECM operation. The planar geometry and modularity of the ECM technology allows for easy configuration into large size systems suitable for deployment in PC plants. In this project, FCE will design and fabricate a small pilot system (nominal 3-MWe equivalent) and test the system on actual flue gas from a slipstream of pulverized coal (PC) plant flue gas for at least two months. A techno-economic analysis and an environmental, health, and safety study of the system will be performed. The project objective is to verify that the CEPACS system can achieve at least 90 percent CO2 capture from PC plant flue gas with 95 percent CO2 purity at a cost of $40/tonne of CO2 captured and at a cost of electricity 30 percent less than baseline CO2 capture approaches.

C-Crete Technologies is developing a new protocol integrating a collection of advanced synthesis and characterization techniques, a thorough combination of lab-simulation and field tests, as well as cost-benefit and socioeconomics analysis to achieve the most beneficial and cost effective CO2 barrier technology. The core synthesis strategy is a bottom-up approach to further develop the knowledge base related to nanoparticles and nanocomposites and apply it to a new cement-based porous nanoparticles (CPNP)-sealant product (Figure 1). The technical results are being coupled to a cost-benefit/ socioeconomic analysis that incorporates materials/method cost structures and risk and environmental priorities to quantitatively evaluate the impact and benefits of the new product and technology.

Montana State University is developing new mineralization precipitation technologies capable of sealing near-wellbore leakage pathways under a variety of pressure and temperature conditions in the presence of carbon dioxide (CO2) and brine to help ensure CO2 permanence within the storage formation. The minerals are promoted by enzymatic and thermal degradation of urea, which results in mineral precipitation. The minerals can withstand significantly greater temperature than certain microbe precipitation techniques explored during previous development efforts. The project is combining the use of laboratory testing at elevated temperatures and simulation modeling to determine the most applicable mineral sealing strategy. The selected strategy will be deployed in a field experiment at the Gorgas Power Station in Walker County, AL, where an attempt will be made to seal a previously-identified fracture zone in a well at the plant site (Figure 1). The longevity of the mineral seal is being assessed with laboratory, modeling, and well logging and characterization techniques. The project team is building on its previous successes with biomineralization technology development by targeting the use of the identified active catalyst enzyme (instead of the entire cell) and direct thermal hydrolysis of urea to drive mineral precipitation. This will facilitate engineered mineralization sealing at greater depths and higher temperatures than is currently possible with biomineralization technology.

Researchers at the University of Illinois, in partnership with the Linde Group, BASF Corporation, Affiliated Engineers, Inc., and the Association of Illinois Electric Cooperatives, will design a 25-MWe, amine-based advanced carbon dioxide (CO2) capture pilot-scale system for integration with the existing coal-fired boilers at the Abbott Power Plant. The pilot plant aims to capture approximately 500 tonnes per day of CO2 with a 90 percent capture rate. The project will utilize the Linde-BASF advanced CO2 capture process, based on the novel BASF amine solvents, which has shown the potential to be cost-effective, energy efficient, and compact at the 0.5-1.5 MWe pilot scales. Through the previous 1.5 MWe pilot testing program at the National Carbon Capture Center, the technology shows promise of driving down the cost of CO2 captured from commercial-scale, coal-fired power plants. During Phase I, the project team will develop the project management plan, preliminary plant design, and cost estimate for the large-pilot plant; update the techno-economic assessment and technology gap analysis based on small-pilot results; and define a test plan to evaluate the integrated absorption system with parametric and long-term continuous testing.

Projects for the large-scale (equivalent of 10 to +25 MWe) pilot testing of post-combustion CO2 capture technology systems are being conducted in two phases, with a competitive downselect to continue from Phase I into Phase II. This project was selected for Phase I; a Phase II application must be submitted to be considered for the full project.

Southern Company Services (SCS) has teamed with Mitsubishi Heavy Industries America and AECOM Technical Services to test improvements to carbon dioxide (CO₂) capture and storage (CCS) processes. The goal of this project is to evaluate the improvements of an integrated stripper/reboiler, particulate matter management, and new solvent on the existing 25 MWe-scale, amine-based Kansai Mitsubishi Carbon Dioxide Recovery (KM-CDR^TM) process at Southern Company's Plant Barry. The KM-CDR at Plant Barry is a fully-integrated CCS plant and has achieved 90 percent CO₂ capture at a production rate of 500 metric tons per day. The large-scale pilot plant uses the proprietary KS-1 solvent, which shows several benefits relative to monoethanolamine-based processes. The key technical challenges of high-steam consumption, solvent performance degradation, and process equipment footprint will be investigated. During Phase I, SCS will perform a preliminary techno-economic analysis, preliminary design, and technology gap analysis; integrate results from previous amine-based CO₂ capture process testing; and define the project plan to include baseline, parametric, and long-term operations testing.

Projects for the large-scale (equivalent of 10 to +25 MWe) pilot testing of post-combustion CO₂ capture technology systems are being conducted in two phases, with a competitive downselect to continue from Phase I into Phase II. This project was selected for Phase I; a Phase II application must be submitted to be considered for the full project.

Research Triangle Institute (RTI), with support from Tampa Electric Company (TEC), will perform additional R&D on the 50 MW syngas slip-stream from TEC’s Polk 1 IGCC facility. This R&D includes extended testing of the warm syngas cleanup pre-commercial demonstration unit for approximately 3,000 additional hours. During this extended operational period, the project would demonstrate capture of CO2 via integration of warm gas cleanup and other pre-combustion capture technologies. During the additional testing, the project intends to establish at least 1,000 continuous hours of fully-integrated operation (including warm gas desulfurization process (WDP), water gas shift, and activated amine carbon capture technology) to reduce the technical risks associated with the integrated processes, and demonstrate that it can operate with high reliability and availability without unexpected process, mechanical, or control issues. A one-year period of performance will allow RTI to complete this extended testing, analyze the data, and develop optimum process configurations for integration of WDP and CO2 capture technologies for production of power, chemicals and fuels through coal gasification.

Altex has identified an innovative technology that leverages the current heat exchanger bonding process to also improve the heat exchanger surface characteristics to address corrosion and erosion as a result of operation with supercritical carbon dioxide. By going to this one step process, heat exchanger corrosion and erosion resistance can be improved, at low cost. Furthermore, the base structural strength of the heat exchanger will remain unchanged.