The Core Carbon Storage and Monitoring Research Program (CCSMR) aims to advance emergent monitoring technologies that can be used in commercial carbon storage projects. In FY17 our program is focused on highly leveraged international collaborations, where LBNL can apply emergent technologies in field monitoring to help accelerate the commercialization of carbon sequestration. The five scientific tasks include three international collaborations, the CO₂CRC Otway Project, the PTRC Aquistore Project, and the CMC FRS program, which are continuations of prior research efforts. A new collaboration under the US DOE-Japan CCS Collaborative Framework is being initiated with the Japanese Research Institute for Technologies of Innovative Technology for the Earth (RITE). LBNL and RITE will use the CMC FRS for testing distributed fiber-optic strain monitoring technologies to observe geomechanical changes induced by CO₂ sequestration. We will also be restarting the Mont Terri research that was previously funded in FY15 to investigate mechanisms governing induced seismicity. The primary technologies that we are focused on are those that can be transformative in continuous monitoring applications over long periods of time that can reduce monitoring costs and improve effectiveness. These include fiber-optic distributed acoustic, temperature, and strain sensing, along with well-based discrete sensing and sampling technologies.

Management of fluid pressures is expected to be a key issue in the implementation of full-scale carbon dioxide (CO₂) storage operations. Injection of CO₂ into the storage reservoir causes fluid pressures to rise in the reservoir, potentially resulting in high rock stresses that can cause reactivation of faults or fracturing of caprock, thus losing its ability to contain the CO₂. At some sites, extraction of saline groundwater from the storage reservoir may be required to maintain safe working pressures when CO₂ is injected into the subsurface and to enhance CO₂ storage capacity and injectivity. The brine from the formation will likely be produced in significant quantities and contain high concentrations of total dissolved solids. With treatment, this water could be desalinated and put to beneficial use at a power station for cooling or for other uses, thus reducing the risk associated with brine re-injection/disposal. The overall objective of this Brine Extraction Storage Test (BEST) project is to help develop cost-effective pressure control, plume management and produced water strategies that can be used to improve reservoir storage efficiency and capacity, and demonstrate safe, reliable containment of CO₂ in deep geologic formations with CO₂ permanence of 99% or better. In addition, operational experience gained from implementing the field demonstration at a power plant site will provide realistic and practical learnings that can be incorporated into future updates of the United States Department of Energy (DOE) best practice manuals related to Carbon Capture and Storage (CCS). In Phase I, the Recipient identified a preferred field site location, conducted life-cycle analyses for produced water extraction, treatment, transportation and residual waste disposal. Monitoring and injection/production strategies were developed for measuring and controlling the subsurface reservoir pressure and injection plume, and a series of work plans for field demonstrations of pressure management and treatment of extracted brines were prepared.

The University of North Dakota Energy and Environmental Research Center (EERC) (Grand Forks, ND), GE Global Research, Computer Modeling Group, and Schlumberger Carbon Services worked together in Phase I of this project to create a technical design package for a brine extraction and storage test. The design focused on validating approaches for active reservoir management and extracted water treatment. Concurrent with site selection activities, viable pilot-ready water treatment technologies were screened for their potential to be deployed at the Phase II site. Surface facilities were designed for the selected site to be flexible and modular, able to accommodate most pilot-ready water treatment technologies.

This BEST (Brine Extraction Storage Test) project was one of two BEST projects selected (through a downselection process) to be continued into Phase II.

In Phase II, EERC is conducting a field validation test of the design developed in Phase I. The field validation effort be integrated with an operating commercial saltwater disposal facility located near Watford City, North Dakota. The objectives of the project are to confirm the efficacy of the active reservoir management (ARM) approaches developed during Phase I for managing formation pressure, predicting and monitoring differential pressure plume movement, and validating pressure and brine plume model predictions. The project will use engineered brine injection and extraction tests, monitoring and verification practices, and iterative simulation modeling to evaluate and understand the effect of various ARM strategies. The project will also implement and operate a test bed facility for the evaluation of selected brine treatment technologies for treating high total dissolved solids (TDS) extracted waters. Project activities will be conducted in three development stages over 48 months, including 1) site preparation and construction, 2) site operations including ARM and brine treatment technology testing and demonstration, and 3) project closeout/decommissioning and data processing/reporting.

This project is designed to validate a technology to enhance the monitoring, verification, and accounting (MVA) of CO₂ injected underground for the purpose of long-term geologic storage and enhanced oil and gas recovery. Specifically, the effort is deploying, validating, and integrating an ultra-high-resolution 3D marine seismic (UHR3D) technology appropriate for large-demonstration and commercial-scale offshore CCS sites. Researchers are acquiring and validating at least one ultra-high-resolution 3D seismic dataset at an operational carbon capture and storage demonstration site. The study will use this data acquisition to validate the innovative, dynamic acoustic-positioning techniques. Subsequently, they will use this information to define the extent and boundaries of the CO₂ plume, and track and quantify the uncertainty of spatial and temporal movement of CO₂ through the reservoir.

This project is developing and validating an integrated package of joint seismic-pressure-petrophysics inversion of a continuous active-source seismic monitoring dataset capable of providing real-time monitoring of a carbon dioxide (CO₂) plume during geologic carbon storage. The resulting real-time map of CO₂ saturation obtained using this process will provide a deeper understanding of the complex, time-varying dynamics of the subsurface fluid flow migration path, as well as the rapid detection of potential CO₂ leakage.

This project is working to develop geophysical contrast agents for enhanced monitoring of injected carbon dioxide (CO₂) in sedimentary rocks and for mapping fracture networks in depleted shale gas formations. The focus of the project is characterizing coupled geochemical, pore network, and geomechanical responses to subsurface fluid-rock interactions that are associated with unconventional reservoirs. The effort is divided into three technical tasks.

This project will expand membership of the Southern States Energy Board’s existing Gulf of Mexico (GOM) government-industry partnership to focus on assembling the knowledge base required for secure, long-term, large-scale carbon dioxide (CO₂) subsea storage. The partnership’s evaluation will focus on active and depleted oil and gas fields and potentially associated CO₂-enhanced oil recovery, as well as deep saline storage resources in the eastern portion of the GOM’s federal and state waters. The partnership will integrate and assess characterization data and infrastructure delivery options and adapt and tailor monitoring, verification, and accounting (MVA) technology applications and geologic and dynamic flow models for offshore CO₂ storage projects. The project will facilitate the subsequent development of technology-focused permitting processes needed by industry and regulators for CO₂ storage in the GOM.

This project will develop an industry/academic/governmental partnership that will assemble the knowledge base required to support use of the geologic environments beneath the Gulf of Mexico (GOM) for secure, long-term, large-scale carbon dioxide (CO₂) storage and enhanced hydrocarbon recovery. The knowledge base created by the Offshore Carbon Storage Partnership will facilitate subsequent development of technology-focused permitting processes needed by industry and regulators. This project will provide an offshore CO₂ resource characterization for the western portion of the GOM through the assessment and integration of geologic and engineering information. The partnership will focus on identifying and addressing knowledge gaps, regulatory issues, infrastructure requirements, and technical challenges associated with offshore CO₂ storage. This project will work to improve the confidence in containment of CO₂ in the subsea offshore environment in storage reservoirs over both short and long timeframes.

This project is developing methodologies to measure the in-situ principal stress in the deep subsurface through use of multiple independent, but complementary seismic methods, laboratory verification, and development of theoretical frameworks. The project is leveraging existing regional and local datasets to develop, test, and refine a set of diagnostic tools for determining the in-situ stress state with reduced uncertainty at and below reservoir depths (1.5-6 kilometers). The goal is to develop a set of novel tools that are scale-independent, such that their utility is equivalent on regional, field scale, and near borehole monitoring of principal stresses in reservoir underburden for carbon storage projects. The research involves applying the virtual seismometer method (VSM) and shear wave splitting (SWS) methods to robust seismicity catalogs created with matched filter techniques near sites of active fluid disposal—a proxy for carbon storage sites where complete datasets are more limited. This is a non-invasive method to determine the orientation and magnitude of the in-situ stress principal stress field over large spatial scales and at depths >1500 meters. Stress estimation methods using seismic processing tools will be validated using controlled laboratory experiments conducted on rock samples from the region of interest. The project is developing theoretical models to provide a framework for understanding the links between local injection information (e.g. local pore-fluid pressure distribution and associated poroelastic stresses), observed changes in spatial and/or temporal principal stress orientations, the absolute magnitude of the stress field, and subsequently observed geophysical signals.

The main goal of the proposed study is to predict the presence of faults that will be susceptible to movement in the presence of fluid injection. Additional goals include: 1) identify the presence of faults, 2) estimate changes to the in-situ stress field before and after fault slippage, and 3) explain pressure and stress perturbations between the storage unit and the crystalline basement (underburden). The project will test a series of integrated forward and physics-constrained, data-driven (inverse) models that includes the following: 1) use of a geologically well-characterized field site with microseismicity located within the basement rock, 2) predictions of temporal and spatial stress changes induced by injection, 3) methodology to better resolve basement faults including undetected faults, and 4) identification of mechanisms, which control and transmit pressure from the storage unit to the basement.

This project is using well-established existing technology to improve the standard methods of in-situ stress measurements by including thermally induced borehole breakout technology for measuring the most compressive principal in-situ stress. By running multiple heating tests in a borehole and correlating different applied temperatures (thermal stress) to breakout measurements, the understanding of local variability at the wellbore can be improved while reducing uncertainty.

The overall objective of this research is to identify economic strategies to co-optimize carbon dioxide enhanced oil recovery (CO₂-EOR) and associated storage in stacked, primarily siliciclastic, reservoirs and residual oil zones (ROZs) in the Illinois Basin (ILB). Achieving this objective will entail (1) verifying the presence of ROZs within the Illinois Basin; (2) developing methods to identify and characterize siliciclastic ROZs; (3) conducting simulation, laboratory, and field-laboratory studies at greenfield and brownfield ROZ field laboratory sites; (4) assessing the economics and performing lifecycle analyses of injection-production scenarios; and (5) conducting a ROZ CO₂-EOR and associated storage resource assessment for the ILB.

This study will address challenges related to co-optimizing CO₂- EOR and associated storage in integrated stacked ROZ storage complexes through computational, bench-scale, and field-laboratory research. Detailed studies will be conducted at two field laboratory sites, one with stacked greenfield ROZs and the other with a stacked complex that includes a brownfield ROZ and depleted conventional reservoirs. The field laboratory sites will be used to collect data and conduct tests to validate ROZ detection methodologies and identify economic, field-deployable strategies to optimize oil production, optimize CO₂ storage, and co-optimize CO₂-EOR and associated storage in stacked ROZs. Findings from these field sites will be extrapolated to characterize the basin wide stacked ROZ fairway CO₂-EOR oil resource and CO₂ storage potential.

The goal of the Energy & Environmental Research Center (EERC) project is to advance associated geologic storage of carbon dioxide (CO2) in the Williston Basin by establishing the Williston Basin Associated CO2 Storage Field Laboratory. This goal will be accomplished through efforts conducted in collaboration with the project partner and current host site operator, SOG Resources, in both field and traditional laboratory settings. The field-based portion of the project will take place in an oil field in the Williston Basin and will involve the injection of CO2 into a stacked storage complex that includes a residual oil zone (ROZ) and a conventional reservoir by the operator. Gas measurements and/or log/core acquisition will be done in the field by the operator, who will provide EERC with core and fluid samples (as well as data and site access) to conduct laboratory efforts at EERC. The project will: (1) generate field-based data on CO2 enhanced oil recovery (EOR) associated storage in stacked reservoirs; (2) characterize ROZ for associated storage; and (3) evaluate a monitoring, verification, and accounting technique for its applicability to associated storage in stacked complexes.

The primary purpose of this project is to establish a field laboratory to assess the technical and economic viability of enhanced oil recovery and associated carbon dioxide (CO₂) storage in the greenfield (“fairway”) residual oil zones (ROZs) of the Powder River Basin. This is being accomplished through four objectives: 1) Characterizing the ROZ fairway resource adjacent to the Salt Creek Oil Field, Powder River Basin; 2) undertaking detailed review of mechanisms influencing the efficiency and permanence of ROZ-associated CO₂ storage; 3) examining alternative CO₂ injection and storage strategies for optimizing both oil recovery and CO₂ storage 4) establishing the commercial viability of enhanced oil recovery and associated CO₂ storage for the ROZ fairway at Salt Creek.

Battelle Memorial Institute combined two Regional Carbon Sequestration Partnerships (RCSPs)—the Midwest RCSP led by Battelle and the Midwest Geologic Sequestration Consortium led by the Illinois State Geological Survey— to form the Midwest Regional Carbon Initiative (MRCI) comprising midwestern and northeastern states. The initiative is supporting key activities, including: (1) expanding regional stress/risk assessment to an additional level of detail in new areas; (2) expanding the acquisition of legacy seismic/well data from small oil/gas producers; (3) evaluating conceptual project definition for Atlantic offshore areas and east coast sources; (4) expanding industrial collaboration efforts to new sites/partners and collecting data from brine injection wells for use in storage assessment; (5) incorporating energy transition issues (e.g., hydrogen, direct air capture, bio-enhanced carbon capture, utilization, and storage (CCUS), cybersecurity, environmental justice, and job creation/workforce development) into infrastructure assessments; and (6) expanding outreach efforts to regional intergovernmental groups and Historically Black Colleges and Universities.

The Carbon Utilization and Storage Partnership of the Western United States (CUSP) was formed as an outgrowth of three former Regional Carbon Sequestration Partnerships: The Southwest Regional Partnership on Carbon Sequestration; the WestCarb Partnership; and the Big Sky Partnership. The primary objective of the CUSP is to catalog, analyze, and rank carbon capture, utilization, and storage (CCUS) options for parts or all of 13 states comprising the contiguous western United States (U.S.). The project team is comprised of academic institutions, government agencies, national laboratories, and industry partners throughout the western U.S. The CUSP coordinates the diverse capabilities and experience of these organizations to accelerate CCUS deployment through the performance of four key activities: 1) addressing key technical challenges; 2) facilitating data collection, sharing, and analysis; 3) evaluating regional infrastructure; and 4) promoting regional technology transfer.

The Energy & Environmental Research Center at the University of North Dakota leads the PCOR Partnership Initiative, with support from the University of Alaska Fairbanks, the University of Wyoming, and over 200 cumulative industrial, organizational, and governmental partners, in fostering the development of carbon capture, utilization, and storage (CCUS) in the northern Great Plains states, adjacent Canadian provinces, and Alaska. Areas included in this region are dominated by fossil energy production and coincide with abundant opportunities for geologic storage in sedimentary basins. The PCOR Partnership is catalyzing CCUS projects in its region by 1) strengthening the technical foundation for geologic CO₂ storage and enhanced oil recovery; 2) advancing capture technology; 3) improving application of monitoring technologies to commercial CCUS projects in the region; 4) promoting integration between capture, transportation, use, and storage industries; 5) facilitating regulatory frameworks; and 6) providing scientific support to policy makers.

The SECARB-USA Initiative is identifying and addressing regional onshore storage and transport challenges facing commercial deployment of Carbon Capture, Utilization, and Storage (CCUS) technologies. SECARB-USA encompasses Alabama, Arkansas, Florida, Georgia, Louisiana, Mississippi, North Carolina, South Carolina, Tennessee, Virginia, and portions of Kentucky, Missouri, Oklahoma, Texas, and West Virginia. The Southern States Energy Board (SSEB) is coordinating the capabilities of a diverse project team to accelerate CCUS deployment by achieving four primary research objectives: 1) addressing key technical challenges; 2) facilitating data collection, sharing and analysis; 3) assessing transportation and distribution infrastructure; and 4) promoting regional technology transfer and dissemination of knowledge.

This project is developing a wireless downhole sensor system to monitor parameters for carbon dioxide (CO₂) storage. The sensor system will be field tested in two legacy oil & gas wells to validate the technology and demonstrate its applicability to monitor CO₂ in the subsurface. The project is designed to leverage the latest in microsensor development and customize wellbore telemetry needs, deployment, and analysis methods to develop a transformative technology directly pertinent to CO₂ storage in the subsurface. Key advancements in knowledge and technology generated through this research include a distributed wireless microsensor system, telemetry system to transmit data to surface without cables, customized deployment options, and a customized approach to processing and integrating sensor data to understand CO₂ distribution and track CO₂ plume movement in the subsurface. Altogether, the project will produce an effective and practical sensor system for CO₂ storage applications.

The main goal of the study is to design and test a monitoring system that will deploy sensors within the casing annulus without the need to perforate casing or run wires/cables in the annulus for sensor installation, power supply, or data transmission. This monitoring system will improve reservoir and above zone monitoring for the expected life of the wellbore. The project utilizes millimeter-scale sensors on a chip to enable transformational, autonomous, near-wellbore reservoir monitoring in the casing annular space. The recipient will optimize a wireless solid-state potentiometric sensor system for the purpose of continuously measuring carbon dioxide (CO₂), pH, temperature, and methane (CH₄) within the high pressure and temperature environments in the casing annulus. The sensors consist of autonomous microelectronic radio frequency tag circuits; with memory and antenna; micro-fabricated on 1mmx1mm sensor chips that can be wirelessly addressed and inductively powered wirelessly by a smart casing collar. Sensor chips will be designed and coated with specialized polymer coatings, enabling sensor survival in the sequestration environment along with preferentially self-locating at the reservoir cement interface or in the cement. Surface chemistries and surface textures will be specially designed to demonstrate self-location in the lab, simulating injecting sensors with drilling mud (circulated after drilling is complete), and the segregation of sensors at the formation surface. Part of the work will also focus on improving, integrating and testing smart casing collars acting as real-time communications routers to complete a real-time integrated intelligent monitoring system.

The overall objective of this project is to perform a comprehensive commercial-scale site characterization of a storage complex located in northwest New Mexico to accelerate the deployment of integrated carbon capture and storage (CCS) technology. The data collected by the characterization and environmental analysis will be used to prepare, submit and attain an Underground Injection Control (UIC) Class VI permit (for construction) to inject and store at minimum 50 million metric tons of carbon dioxide (CO₂) at the site. The project team will acquire new field data and integrate new and legacy information to develop comprehensive site-specific data sets that will be used as inputs for the preparation process of a UIC Class VI permit that will be submitted for approval. Data will be incorporated into simulation models to assess storage potential, CO₂ behavior, seal integrity and risk of induced seismicity. An Environmental Information Volume (EIV) will be completed to assess any National Environmental Policy Act (NEPA)-related issues for the chosen capture, transport and storage site. The project team will continue existing outreach programs to educate the public on the usefulness of the integrated CCS project within the region.

The project team will characterize a commercial-scale regional geologic storage complex for carbon dioxide (CO₂) captured from three Southern Company facilities; Plant Ratcliffe (the Kemper County Energy Facility), Plant Daniel, and Plant Miller. The project team will complete detailed characterization work essential for acquiring Underground Injection Control (UIC) Class VI Permit(s) to construct the wells at the Kemper Regional CO₂ Storage Complex, including drilling three additional site characterization wells, conducting a substantial 3D seismic acquisition, and undertaking risk assessment, public outreach, and other tasks. In addition a CO₂ capture assessment will be performed for Plant Ratcliffe and Plant Miller.

This CarbonSAFE Phase III effort aims to build upon the progress of previous phases and advance towards the full commercial deployment of carbon capture, utilization, and storage (CCUS) in Wyoming’s Powder River Basin (PRB). Previous Wyoming CarbonSAFE project phases have demonstrated the feasibility of injecting commercial volumes of carbon dioxide (CO₂) at the proposed storage complex on the property of Basin Electric Power Cooperative’s (BEPC) Dry Fork Station (DFS). DFS is coal-based electric generation power plant that has been proposed as the project’s CO₂ source. Collocated at DFS is the Wyoming Integrated Test Center, a research facility dedicated to CCUS advancement.

The intent of this project phase is to finalize surface and subsurface site characterization and certify the safety and security of eventual commercial CCUS operations at DFS. Applications for underground injection control (UIC) Class VI permits to construct will be submitted and project personnel will work with regulatory authorities until the appropriate permitting is acquired. The team will prepare an Environmental Information Volume (EIV) to inform the project’s final National Environmental Policy Act (NEPA) class of action; this will result in a final NEPA document containing either a Record of Decision or Finding of No Significant Impact. This project will incorporate Membrane Technology and Research’s (MTR) DFS CO₂ front end engineering and design (FEED) and CO₂ capture analysis into the project’s commercialization assessments. This analysis will detail the operational performance of a commercial-scale CO₂ capture plant at DFS.

Two separate but geographically proximate sites – one at the One Earth Energy (OEE) ethanol plant near Gibson City, Illinois, and one at the Prairie State Generating Company (PSGC) coal-fired power plant near Marissa, Illinois – will be characterized for large-scale (50 million metric tons) storage of carbon dioxide (CO₂) captured from those facilities. Characterization activities at both sites include 2D and 3D seismic surveys, stratigraphic test wells and geophysical logs, well hydraulic testing, CO₂ capture and transport feasibility assessment, and detailed injection modeling. The anticipated outcome of the project is the acquisition of permits to install injection wells at both sites under U.S. EPA’s Class VI Underground Injection Control (UIC) regulations.

The objective of the proposed Energy & Environmental Research Center (EERC) effort is to accelerate wide-scale deployment of carbon capture, utilization, and storage (CCUS) by characterizing two safe and cost-effective commercial-scale storage sites within a storage complex in central North Dakota. These sites will safely and permanently store the nominally 3.1 million metric tons (Mt) of CO₂ emissions planned for annual capture from the 455-megawatt Unit 2 of the Milton R. Young Station (MRYS) near Center, North Dakota. The main activities of Phase III (site characterization and permitting) are geophysical surveys such as seismic and electro-magnetic surveys as well as drilling of a geologic characterization well. The EERC also plans to test target formation injectivity with a small scale CO₂ injection test. Information from these various characterization methods will serve as the basis for the Environmental Information Volume (EIV) which this project will develop to assist in the determination if the project will be subject to an Environmental Assessment (EA) or Environmental Impact Statement (EIS).

The New Mexico Institute of Mining and Technology, along with partners at Los Alamos National Laboratory, Silixa LLC, and the University of Utah, will carry out field deployment of an integrated suite of cost-effective and novel geophysical, geochemical, and geomechanical technologies for detection and characterization of faults and fractures above and below a target carbon dioxide (CO₂) injection zone. The project team's objectives are to: (1) deploy the latest field technologies, including an integrated behind casing fiber optic sensing system, at a characterization well drilled under the San Juan Basin (SJB) CarbonSAFE project; (2) utilize novel geochemical technology to analyze drill cuttings and core to locate faults (including aseismic faults) and estimate fault sizes and orientations; (3) detect faults in the subsurface environment near the well bore, including faults in the crystalline basement rock, using a novel multi-scale U-Net machine learning method to evaluate 3D surface seismic and 3D VSP images; (4) perform wellbore analysis to identify formation structures such as fractures and faults from wellbore data and characterize formation geomechanical behavior at different scales; and (5) integrate the technologies to develop advanced rock physics and coupled thermo-hydrodynamic-mechanical models in combination with the Monte Carlo method to determine the state of stress on each mapped fault as well as estimate long-term slip potential and/or maximum fault slip potential during large-scale CO₂ injection. Field activities will be completed at the SJB CarbonSAFE site.

This project is producing new cost-effective, and self-validating fault/fracture detection and characterization algorithms using surface seismic data. New methods are being developed to detect and directly image large-scale, previously unidentified crystalline basement faults and associated small-scale fractures. Direct imaging of faults and fractures represents a major advancement over conventional workflows in which faults and fractures are interpreted from seismic images. Indirectly juxtaposing the imaged faults and fractures in a 3D geological model will yield crucial interpretable information about the subsurface stress field and the maximum magnitude of a potentially induced earthquake in the basement. A synthetic dataset and a multicomponent 9C field seismic dataset acquired at Wolf Springs Field in central Montana will be used to validate these methods. The use of multicomponent seismic data can yield consistent imaging results. This work will provide new and crucial information during the site selection phase for geologic carbon storage and seismic hazard assessment.

This project is developing a technique capable of locating and predicting the movement of carbon dioxide (CO₂) within a deep subsurface storage complex by detecting and analyzing acoustic emissions (AE) signals generated by the migration of CO₂ from a storage reservoir into an overriding geologic confining unit. The technique includes a theoretical, physics-based model capable of predicting AE signals from CO₂ flow in porous media, which will be validated with laboratory experiments and fluid flow simulations.

This project is developing a new strategy for monitoring seal integrity combining borehole-based Continuous Active Source Seismic Monitoring (CASSM) with next-generation distributed acoustic sensing (DAS) acquisition to improve the resolution and economic viability of such approaches. Prior generations of borehole sources used for CASSM radiate in the kHz range while DAS tends to have problematic optical noise above 500 Hz; this mismatch will be remedied by (a) development of a new borehole source tuned to lower frequencies; and (b) employing a new DAS interrogator design with improved response in the kHz range. These advances in acquisition technology will be paired with research into relevant processing including novel time-lapse full waveform inversion (FWI) approaches and coda wave analysis techniques. This combined approach will be tested at two different field locations: (1) a shallow (100 m depth) borehole test site located on the Rice University campus in Houston, Texas (the Rice Subsurface Test Facility – RSTF); and (2) the Mont Terri Underground Research Laboratory in Switzerland, where an existing array of 23 boreholes equipped with behind-casing fiberoptics will be used to validate the technology during a sequence of controlled fault leakage experiments. These tests will probe the capacity of the CASSM/DAS approach to quantify low-rate leakage scenarios which would be missed by conventional monitoring approaches.

This project is addressing key barriers to commercial scale deployment of carbon storage by mineralization. Modeling tools that incorporate critical insights from field and laboratory studies, including a sensitivity analysis on reaction rates of key minerals and phases in basalts are being developed, this includes a modeling tool that can simulate the reactivity of water-bearing supercritical carbon dioxide (CO₂) fluids in a reservoir. The project is also identifying dominant fluid flow regimes within the basalt reservoirs that can be manipulated during CO₂ injection to minimize impacts on reservoir porosity and permeability. Additionally, researchers are establishing a baseline modeling approach, benchmarked by laboratory studies, to accurately simulate formation water recovery post CO₂ injection, support permitting efforts, and develop engineered injection strategies for restoring ground water chemistry to the natural state.

The project is evaluating waste residues/waste by-products from various industries for applicability to creating value-added products through carbon dioxide (CO₂) mineralization (CO₂M). The project will apply the CO₂M technology to several waste residues from local industry that broadly represent heavy industries that are widespread throughout the nation. The results of these laboratory experiments will be used to develop a database and toolset to aid in locating and evaluating potential industrial residues that can create value-added products using the CO₂M technology.

The overall objectives of this project are to identify the optimum processes to maximize carbon dioxide (CO₂) sequestration, enhance the efficiency of carbon mineralization, improve the technology readiness of carbon mineralization, and build and advance the required industrial waste concrete base. This project is based on preliminary research done by the University of Nebraska- Lincoln that determined that the physical, mechanical, and durability properties of recycled concrete aggregates (RCA) could be significantly improved after the carbonation reaction with CO₂ in the project team's specially designed small- and large-scale reaction chambers.

This project is determining whether the submerged flanks of extinct Hawaiian volcanoes can be used to effectively mineralize captured anthropogenic carbon dioxide (CO₂), thereby mitigating the increase of atmospheric CO₂ concentrations. Although subsurface storage of supercritical CO₂ has been extensively researched, sequestration in basalt has the advantage of converting CO₂ to immobile carbonate minerals within decades to centuries. The ultimate outcome of this project will be a quantitative assessment of the value of subsurface basalts as a permanent sequestration option and a model that will allow for extrapolation of these results to other parts of Hawai’i and to many other basalt terranes.

The overall objective of this work is to characterize and document the volumetric extent, mineralogy, critical mineral content, petrophysical characteristics, and reaction rates of subsurface mafic and ultramafic rocks within the United States (U.S.), where large amounts of carbon dioxide (CO₂) can be stored as carbonate minerals via carbonation reactions. Previous studies on magnesium-silicate bedrock have focused on surface mapping, where temperature and pressure conditions are suboptimal for sequestration of large volumes of CO₂. Thus, this project focuses on subsurface mapping and characterization of different rock types where in-situ CO₂ injection and sequestration can be conducted. To determine the sites with the highest potential for safe, permanent CO₂ storage, this project is conducting a source-to-sink assessment.

The project objective is to create and disseminate a Mafic Materials Resource Inventory (MMRI) for Arizona and couple this inventory with a systems design analysis that will produce a Direct Air Capture (DAC) to CO₂ Mineralization (DACM) model for industry use. The project team will combine existing physical, chemical, and hydrologic data for young, surficial scoria deposits with new geologic mapping, sample collection, physical and geochemical analyses, volumetric estimations, and mineral carbonation rates, to populate an ArcGIS geodatabase of mafic materials in four volcanic fields across geologically unique regions of Arizona. Specimens will be processed and reacted using a one-step aqueous mineralization approach with simulated saline water resources at variable water loads to benchmark against mafic silicate and alumina-silicate materials assessed elsewhere. The DACM model is a deliverable of the project and will include a technoeconomic analysis and life-cycle analysis of using DAC to mineralize CO₂ in scoria ex-situ.

This project will study the potential of natural materials and industrial mine wastes, within the United States (U.S.) Mid-Atlantic region, to store large amounts of CO₂ via in-situ and ex-situ mineralization processes. More specifically, the project will assess the reactivity of mafic and ultramafic formations and crushed mine and industrial wastes with CO₂, and their post-mineralization physical properties. The project will work in collaboration with the Virginia Department of Energy to accomplish the projects main objectives. The project will analyze the geologic data collected from the U.S. Mid-Atlantic region to determine the suitable rock types. Laboratory scale CO₂ mineralization reaction tests of the suitable target formations and rock types will be done, as well as laboratory scale tests and simulations of the post-mineralization properties of the samples. The laboratory scale tests will be upscaled to field scale. The rock types will be ranked in terms of their suitability for carbon storage. Machine learning capabilities will also be used to determine reaction rates, rock properties, accessibility, associated costs, and to understand nearby regions by extrapolating out from the study area. The project will provide a database and map of the potential carbon storage resources.

Project Lochridge is supporting the U.S. Department of Energy's (DOE) Carbon Storage Assurance Facility Enterprise (CarbonSAFE) Phase II Program by assessing the feasibility of an offshore storage complex in the federal waters of the Gulf of Mexico. The project aims to achieve the five following objectives: 1) Demonstrate that the subsurface saline formations at the offshore storage complex can safely and permanently store at least 50 million metric tons (MMT) of captured carbon dioxide (CO₂) over a 30-year period; 2) Conduct meaningful engagement and two-way communications with communities and stakeholders to inform project planning and design, address societal concerns and impacts, and seek opportunities for economic revitalization and job creation; 3) Identify commercial project risks and develop a comprehensive mitigation strategy; 4) Develop a technical and economic feasibility assessment; and 5) Develop a plan for subsequent detailed site characterization to support Bureau of Safety and Environmental Enforcement (BSEE) Outer Continental Shelf (OCS) permit readiness.

The overall objective of this project is to identify and assess the statewide resources for potential carbon dioxide (CO₂) storage via mineralization process, including basalt formations and mining wastes (termed as resource rock), and characterize the targeted storage site/complex to provide insights on its storage capacity. (See Figure 1.) Project tasks include: (1) pre-screening the potential location in New Mexico and surrounding areas through processing existing data and selecting the optimum sites for further consideration; (2) conducting site characterization and mapping as well as collecting regional geology, hydrology, injection zone, and other relevant geologic information in the field of the identified storage location/complex; (3) collecting legacy resource rock samples for detailed petrographic, petrologic and geochemical characterization to diagnose reactive mineral content and potential environmental hazards, and investigate the geophysical and geomechanical properties of the targeted storage site/complex to advance the CO₂ storage capacity estimation; (4) evaluating the reaction rate between CO₂/fluid and minerals and the storage capacity of the site/complex in both ambient and field conditions to indicate the optimum scenario for CO₂ storage via mineralization; and (5) performing a series of stakeholder related outreach and connection activities to identify the main challenges and concerns from the community.

This project is determining the feasibility of an integrated carbon storage project in the Southeastern Michigan Basin. The project objective is to advance the commerciality of carbon capture and storage (CCS) in the Southeastern Michigan Basin while supporting diversity, equity, inclusion, and accessibility (DEIA); disadvantaged communities; and environmental justice communities. The project team plans to complete detailed site characterization, including drilling a stratigraphic test well and analyzing site geology. Additionally, the project will model the storage reservoir, perform a risk assessment, conduct public outreach and engagement, and develop the needed plans to draft an Underground Injection Control (UIC) Class VI permit.

The Wyoming Trails Carbon Hub (Project WyoTCH) is working to develop a statewide carbon dioxide (CO₂) transportation network capable of transporting 25 million tonnes of CO₂ per year (25 Mt CO₂/yr). The project aims to accelerate the development of a commercial-scale, open-access CO₂ pipeline by leveraging and building on portions of the Wyoming Pipeline Corridor Initiative (WPCI). The project is conducting a detailed front-end engineering design (FEED) study for a ~600-mile pipeline connecting 29 carbon capture sources to 7 geological storage sites. The FEED study includes an Engineering Design Package, Regulatory Plan, Community Benefits Plan, Business Case, and Environmental Safety and Health assessment conducted on an optimized pipeline route. In addition, the FEED study is evaluating the feasibility of expanding the pipeline network to collect, transport, and store as much as 45 MtCO₂/yr.

The Sutter County Carbon Dioxide (CO₂) Capture and Storage Project in the central Sacramento Basin of Northern California will support the Department of Energy's Carbon Storage Assurance Facility Enterprise (CarbonSAFE) program as a Phase II project, which will consist of an assessment of the feasibility for a storage complex within the region's Area of Interest (AOI). The storage complex will be evaluated via data collection from the drilling of a stratigraphic test well within the AOI, associated testing, geologic, reservoir and geomechanical modeling, risk assessment and mitigation/monitoring planning, CO₂ source and transport planning, analysis of contractual and regulatory requirements, a technical and economic feasibility assessment, and a data verification for a future Phase III Underground Injection Control Class VI permit application. Additionally, the project team will further develop and implement community outreach activities addressing Diversity, Equity, Inclusion and Accessibility, the Justice40 Initiative, Community and Stakeholder Engagement, and Economic Revitalization and Job Creation.

The Coastal Bend Carbon Management Project: CarbonSAFE Phase II is working to establish the feasibility and cost of commercial deployment of geological carbon-storage technologies in the Coastal Bend Region of the Texas Gulf Coast. The location of interest is a multi-source hub of onshore storage facilities proximal to the Port of Corpus Christi as the cornerstone of a centralized, multi-faced carbon management solution at the Port of Corpus Christi. Objectives include to: quantify subsurface storage resources; refine reservoir targets/priorities for permanent storage of commercial quantities of carbon dioxide (CO₂); design surface facilities to ensure safety, identify risks, mitigants, costs, and legal and regulatory requirements as a key step in developing a mitigation and monitoring plan; conduct a full spectrum cost-benefit analysis that captures the environmental and socio-economic impacts; and develop two-way outreach and engagement program that promotes equitable, inclusive economic development and seeks to prioritize benefits to historically disadvantaged communities.

This project is determining the feasibility of establishing a commercial-scale regional geologic storage complex for carbon dioxide (CO₂) in Shelby County, Alabama. The project objective is to complete detailed characterization work, including drilling a stratigraphic test well, evaluating the petrophysical properties of targeted formations, and interpreting wellbore geology from lithologic logs. Additionally, the project team plans to perform a risk assessment, conduct public outreach and engagement, evaluate infrastructure for CO₂ transport, and evaluate U.S. Environmental Protection Agency (EPA) Class VI Underground Injection Control (UIC) needs for the region.

The primary objective of the CarbonSAFE Phase II project, the Tulare County Carbon Storage Project (TCCSP), is to establish a commercial-scale carbon dioxide (CO₂) sequestration hub capable of storing and injecting at least 50 million metric tons of CO₂ over the course of 30 years in the California Central Valley. Current estimates suggest the project site can geologically store nearly 500 million metric tons of CO₂; the TCCSP team will seek to verify the geologic suitability of such estimates through the drilling of a stratigraphic test well and analysis of pertinent recovered geologic data from the test well. The project team will develop a roadmap for required permitting and project development activities to determine the most feasible project deployment scenarios, including CO₂ sourcing and routing options. Permitting activities will be tailored to Underground Injection Control Class VI injection well permit standards as well as California Air Resources Board (CARB) low carbon fuel standard certification specifications. In addition to its technical and commercial objectives, the project team will collaborate with local communities, stakeholders, United States Environmental Protection Agency (Region 9) and CARB to share project information and gather feedback to adapt TCCSP’s technical approach as well as a societal considerations and impacts (SCI) strategy. The SCI strategy will factor in environmental and energy justice, community outreach, and diversity, equity, inclusion, and accessibility aspects of the current and future phases of the project. As a key component of this strategy, the TCCSP team will conduct community engagement workshops to gather feedback and consequently implement an outreach-action-feedback approach to incorporate feedback into project plans.

The objective of this project is to determine the feasibility of developing a commercial-scale carbon dioxide (CO₂) geologic stacked storage complex able to safely, permanently, and economically store 50+ million metric tons (MMT) of CO₂ in northwestern North Dakota. The storage complex is being evaluated for storing CO₂ aggregated from multiple sources in a stacked storage configuration. CO₂ will be captured from several gas-processing plants in the area owned and operated by the project partner and a planned gas-to-liquids (GTL) plant in the project area. This effort is bolstered by progressive North Dakota pore space ownership and long-term liability laws, North Dakota primacy of the U.S. Environmental Protection Agency’s (EPA’s) Class VI CO₂ injection regulations, and commitment from local, regional, and state-level stakeholders. These elements, in combination with a motivated, experienced team, create an ideal synergistic scenario for ensuring success of the Carbon Storage Assurance Facility Enterprise (CarbonSAFE) project and promoting national energy security through carbon management.

The Mitchell CarbonSAFE Phase II Project is a feasibility study with the goal of geologically characterizing potential geologic storage complexes within Cambro-Ordovician strata in Mitchell, Indiana. The study will determine the feasibility of the site for geologic storage of carbon dioxide (CO₂). The CO₂ will be sourced from the Heidelberg Materials US, Inc Mitchell Cement Plant. Characterization efforts will consist of drilling a 7,000-foot-deep stratigraphic test well and performing a 50 linear mile two-dimensional seismic survey. Lithostratigraphic geologic data will be gathered from the stratigraphic test well and used to evaluate the storage resources using the Storage Resource Management Systems (SRMS) classification scheme. Structural interpretations of the site’s subsurface will be made from the seismic survey. All project objectives will be completed within 24-months in one budget period. The project consists of six tasks and has six subrecipients that will be contributing to the project tasks at varying levels of engagement.

Hermiston Oregon Basalt Carbon Storage Assurance Facility Enterprise (HERO) will conduct a feasibility assessment of the technical and non-technical aspects of an integrated carbon capture and storage (CCS) project south of Hermiston, Oregon. The project team will examine the potential of carbon dioxide (CO₂) storage via mineralization trapping in basaltic rocks. Mineralization trapping in basaltic rocks is an attractive alternative option for emitters located far from high-capacity CO₂ sedimentary basin storage resources. The potential for rapid mineralization of CO₂ in basalts and the widespread geographic distribution of basaltic formations in the Pacific Northwest offers a potential unconventional, high-capacity CO₂ storage opportunity. Research into mineralization trapping in basaltic rocks needs further investigation to determine the best practices for sustained CO₂ injection at the commercial scale.

The goal of this CarbonSAFE Phase III project is to develop the Lone Star Storage Hub, a large-scale carbon dioxide (CO₂) sequestration complex consisting of two storage facilities along the Texas Gulf Coast. Project tasks include filing for U.S. Environmental Protection Agency (EPA) Class VI “Authorization to Construct” permits at both locations, completing the characterization of the storage facilities, optimizing the storage field development plans to reduce risk, developing and deploying monitoring technologies needed to ensure the non-endangerment of underground sources of drinking water (USDW), completing the United States Department of Energy (DOE) National Environmental Protection Act (NEPA) process and compiling and executing a Community Benefits Plan. Engineering studies are being performed for the associated CO₂ sources and pipeline network.

The Longleaf CCS Hub project seeks to significantly reduce the carbon emissions of south Alabama through the development of a stacked storage hub in proximity to Bucks, Alabama. SSEB and partnering organizations will complete permitting, characterization, and National Environmental Policy Act (NEPA) efforts, characterize the deep subsurface through seismic methods and drilling a deep characterization well, and receive a Class VI underground injection control (UIC) permit to construct. Parallel efforts include the development of a pipeline FEED study and a CO₂ source feasibility study and implementation of a robust community benefits plan (CBP).

This CarbonSAFE Phase II project is collecting and analyzing new, state-of-the-art data to comprehensively characterize the storage complex in a manner that is consistent with the Environmental Protection Agency permitting standards. Major activities include drilling, coring, and logging a 12,000 feet deep stratigraphic test well, and extensive analogue and outcrop mapping and data sampling. These new datasets complement a pre-existing dataset that contains core and geologic data. The collected data will be analyzed using state-of-the-art carbon capture, utilization, and storage (CCUS) technologies that have been derived from previous and ongoing CCUS demonstration projects and the National Energy Technology Laboratory (NETL) comprehensive Best Practice Manuals for CCUS (NETL, 2017). The analyzed data will be used for site characterization, modeling and simulations, risk assessments, site management and monitoring plans, potential underground injection control class VI well permits, and to determine technical/economic feasibility and societal considerations.

The goal of this project is to advance development of a large-scale commercial geologic carbon dioxide (CO₂) storage hub in central North Dakota to safely and permanently store up to 200 million metric tons of CO₂. The proposed storage hub would store up to 8.9 million metric tons per year of CO₂ captured from the Coal Creek Station power plant and up to 200,000 metric tons per year of CO₂ captured from the Blue Flint Ethanol plant, which is colocated with Coal Creek Station. Project efforts being led by the University of North Dakota's Energy & Environmental Research Center, in partnership with Rainbow Energy Center and Neset Consulting Services, Inc., include site characterization and permitting. The main activities of this project are to acquire 3D seismic data, drill a geologic characterization (stratigraphic test) well, conduct a pipeline front-end engineering and design (FEED) study, prepare North Dakota underground injection control (UIC) Class VI permit applications, and generate National Environmental Policy Act (NEPA) documentation such as an environmental information volume (EIV) and subsequent environmental assessment (EA) or Environmental Impact Statement (EIS). In addition, the project team will identify societal considerations and impacts of the proposed research, including both positive and negative impacts on disadvantaged communities and subpopulations, and develop and implement region-specific plans to engage communities and stakeholders.

Western Michigan University (Kalamazoo, Michigan) is supporting the Regional Initiative to Accelerate Carbon Management Deployment to reduce the risks associated with commercial-scale geologic storage of carbon dioxide (CO₂), advance the understanding of carbon management technology within communities, and ensure the long-term, safe, and equitable storage of CO₂.

The project will focus on the Michigan Basin and consists of four main technical tasks, (1) development of a Societal Considerations and Impact (SCI) Plan, (2) mapping of the geographic areas of interest, (3) assessment of the confining units, and (4) development of a wellbore integrity assessment tool.

The SCI plan will consist of carrying out community and stakeholder engagement plans, evaluation of disadvantaged and environmental justice communities, and development of community benefit portfolio plans. Mapping of the geographic areas of interest will be done by compiling existing geographic data to develop a comprehensive database and detailed maps of the storage reservoirs and brine disposal reservoirs. Assessment of the confining units will be done by analyzing existing geologic data and gathering and producing new data that will be used to map and evaluate the confining systems immediately overlying the key reservoirs. The wellbore integrity assessment tool will be created to help identify wells with leakage risk. The tool will be developed by integrating wellbore data with the produced confining system and reservoir maps.

Anticipated outcomes of this project consist of a database of geomechanical and lithological data, a wellbore integrity assessment tool, and an integrated user-friendly tool for geologic and societal considerations assessments.

The Prairie Horizon Carbon Management Hub project team will provide technical assistance and facilitate public engagement in support of creation of a regional carbon management hub (HUB) in North Dakota. Technical assistance includes evaluation of geologic data collected within the project area to better understand reservoir characteristics and infrastructure needs associated with the development of the HUB. Public engagement efforts consist of collaborations with stakeholders, including those from nearby communities as well as the broader technical community.

This project will fill subsurface knowledge gaps in the San Juan Basin and Four Corners region that are needed to enable the deployment of carbon management activities, including Carbon Capture Utilization and Storage (CCUS) for emission mitigation efforts within the industrial and power sectors. The knowledge gaps will be filled through six project objectives. The first objective is to collect, analyze, and disseminate data. The analyzed data will be used to ensure the safe capture, removal, efficient injection, storage, and monitoring of carbon dioxide in the San Juan Basin and Four Corners region. The second objective is to obtain, reprocess, interpret, and analyze existing seismic data to understand the structural history of the western margin of the San Juan Basin. Additionally, the seismic data will be used to implement seismic de-risking measures pertaining to CCUS activities. The third project objective is to improve the current geological model of the region by integrating newly interpreted seismic data with previously interpreted seismic and well log data. The improved geologic model will be used to identify fault locations and determine the three-dimensional characteristics of the Hogback monocline. The project's fourth objective is to characterize the present day heat flow and thermal regime of the San Juan Basin as well as its thermal tectonic history and temperature variations in relation to reservoir characteristics. The fifth objective is to perform the following: a probabilistic resource assessment of the San Juan Basin, a quantitative estimation of porosity and permeability, and an investigation into the storage of produced water as a means of pressure management. The sixth objective is to promote environmental justice and perform outreach activities and give an education to industry stakeholders, communities, and the public on CCUS.

The objective of this project is to build a database using existing subsurface, surface, and societal data for entities screening areas of Illinois for commercial geologic carbon dioxide (CO₂) storage. Sub-objectives are to; 1) test the database using play-based exploration and analyses methods to create composite maps that clearly delineate areas in the state with the lowest risk for storage site development, 2) share the database with the United States Department of Energy (DOE), the original Regional Initiative projects, and Recipients un DE-FOA-0002799, and 3) provide the public with access to the database and resulting composite maps, specifically those screening Illinois for commercial storage sites or those potentially impacted by the development of such sites.

The Alabama Carbon Storage: Data Sharing and Engagement Project (Project) seeks to compile geologic, geophysical, infrastructure, and other relevant datasets for the Gulf Coastal Plain of Alabama through the development of a geologic model of the study area. The Geological Survey of Alabama and partnering organizations will develop an online platform to serve data to stakeholders, and to engage with the public, students, and industry to educate them about Carbon Capture and Storage. Additionally, the Project will integrate Environmental Justice considerations into all aspects of the project.

The main objective of the Central Appalachian Partnership for Carbon Storage Deployment Project is to reduce barriers for entry to carbon storage project opportunities, particularly in the deepest parts of the Appalachian basin. Meeting this Project’s objective will help to accelerate the deployment of Carbon Capture, Utilization and Storage (CCUS) in Pennsylvania and West Virginia. The Project will build upon CCUS characterization efforts for the Appalachian basin and combine the expertise of two state geological surveys, 1. The Pennsylvania Geological Survey, and 2. The West Virginial Geological and Economic Survey. The Project will engage regional stakeholders and technical assistance partners. Additionally, the Project will contribute to value-added technical and geologic information to the regional knowledge base. Project deliverables will become significant resources for CCUS deployment in the Appalachian Region.

The objective of The Oklahoma Geological Survey Coordination of Mid-continent Carbon Management project (Project) is to provide an assessment of geological carbon storage opportunities in Oklahoma (OK) by integrating new and existing core and borehole data with subsurface imaging and coordinating all work with applicable Regional Initiatives. The Project will work to complete geologic assessments and monitoring trial deployments to improve a web-based geologic data repository for OK. Data acquisition will include gathering seismic data from an array of stationary seismometers and collecting pressure monitoring data from an array of downhole monitoring apparatuses. The project will assess deep saline aquifers in OK for carbon dioxide storage, with particular attention to Arbuckle and non-Arbuckle targets. Additionally, the Project will develop a local community engagement program around carbon management in OK and will encourage further carbon management and Carbon Capture Utilization and Storage (CCUS) activities through developing and providing capacity building at the state-agency level.

The Indiana Geological and Water Survey (IGWS), housed within Indiana University (Bloomington, Indiana), is supporting the Regional Initiative to Accelerate Carbon Management Deployment through this Project by helping to reduce the risks associated with commercial-scale geologic storage of carbon dioxide (CO₂), advance the understanding of carbon management technologies within communities, and ensure the long-term, safe, and equitable storage of CO₂. The project will identify and evaluate areas in Indiana with saline reservoirs that exhibit favorable geologic parameters for carbon sequestration. Focus Areas will be identified and evaluated via the compilation, digitization, and analysis of new and historic subsurface data; laboratory analysis of existing geologic samples; comprehensive geologic characterization; development of new maps and updates to existing maps essential for carbon storage decision-making; and evaluation of the legislative, societal, and infrastructural conditions that impact the Focus Areas. This collected data will be utilized to quantify the storage capacity of the system, characterize the shallow subsurface to understand risk from unintended migration, and develop a Community Benefits Plan for each area based on community engagement feedback. Data findings will be consolidated into a publicly available GIS database. The GIS database will provide crucial information needed for CO₂ hub siting, as well as initial recommendations for areas in Indiana that may be best suited for geothermal production, hydrogen storage, and CO₂ storage activities.

This project is establishing a foundation for carbon capture and storage (CCS) by addressing technical challenges, environmental factors, and stakeholder engagement to meet the need for development of an offshore hub in the Cook Inlet region of Alaska. The project is assisting industry and communities in evaluating the viability of storage scenarios and identifying environmentally and socially sensitive areas. To accomplish this, the project team is gathering, analyzing, and sharing data to inform development of large-scale storage facilities; engaging state and federal agency databases, researchers, and publications to assess regionally available data; and developing a data distribution plan and portal for the State of Alaska to share information, research, outreach materials, and regulations regarding carbon storage.

The Utah Statewide Carbon Storage Assessment: Geological Data Gathering, Analysis, Sharing, and Engagement Project (Project) will work to aggregate, analyze, and disseminate organized and accurate geological data for the carbon storage (CS) aspect of carbon management in the state of Utah. The Project covers the entire state of Utah with a focus on specific regions highlighted following initial characterization work. The overarching objective of the project is to develop publicly available comprehensive datasets to support the characterization and interpretation of CS resources at both regional and site-specific scales in the state of Utah. The developed datasets will also note societal and environmental impacts of CS for the state of Utah.

This project will complete a Front-End Engineering and Design (FEED) study of a carbon dioxide (CO₂) pipeline capable of transporting up to 250 Million Metric Tons (MMT) of CO₂ annually to locations along the Texas and Louisiana Gulf Coast. The FEED study will integrate multiple CO₂ source hubs and emission clusters along the route, creating access to onshore and offshore geologic storage sites that would not otherwise exist. The project team will utilize industry standard practices to identify the optimal routing for the pipeline and engineering design of the transport network. Routing will consider existing rights-of-way, stakeholder needs and concerns, and potential CO₂ sources and sinks.

This project is studying the multiphase flow behavior related to the transportation of carbon dioxide (CO₂) and impurities. The flow behavior of CO₂ is being investigated for injection wells and through pipelines. To accomplish this, the project is investigating and evaluating flow models for well injection and pipeline transport; preparing a mesoscale test bed for CO₂ flow experiments; and investigating multiphase of CO₂ and impurities under various configurations, targeting problematic flow regimes.

The ultimate goal of this project is to develop a Carbon Hub Roadmap for Project WyoTCH. The Roadmap has two key aims. First, it will be used by the development team to develop a sustainable open-access carbon hub, and to help develop a feasible business case, design the carbon capture and storage (CCS) infrastructure (where, when, and how to capture, transport, and store carbon dioxide [CO₂], including uncertainty and sensitivity analysis), raise financing, and construct and operate the hub. Second, it will serve as a blueprint or set of lessons learned to support the development of other open-access carbon hubs across the nation, with emphasis on a template for proactive, authentic community stakeholder engagement. The Roadmap will be developed in collaboration with communities and stakeholder groups and disseminated through a variety of mediums, including U.S. Department of Energy workshops.

The project is developing a geologic site characterization database, called the Wyoming Class VI Site Characterization Database, to expedite Underground Injection Control Class VI permitting for potential carbon storage hubs in southwest Wyoming’s Greater Green River Basin. Specifically, the project will build a database of information compiled and verified from established, public geologic databases/entities, and provide a record of key social considerations and community benefits which developers should address or consider when preparing Underground Injection Control (UIC) Class VI applications.

This project is establishing a foundation for carbon capture and storage (CCS) by addressing technical challenges, analyzing environmental factors, and facilitating stakeholder engagement to meet the need for development of a mid-Atlantic offshore hub. The project is evaluating the viability of multiple design scenarios through developing and executing plans for community benefits activities, defining realistic carbon dioxide (CO₂) storage resources, affirming injection scenarios, and building site characterization plans. Accomplishing these tasks requires collaborating with industry to build on prior data collection and analysis; evaluating CO₂ transport scenarios; source-sink matching; analyzing environmental factors, offshore infrastructure scenarios, and policy/regulatory gaps; and conducting workshops and outreach to key policy and regulatory stakeholders. The project team includes Battelle, Aker Solutions, Lamont Doherty Earth Observatory, Maryland Geological Survey, Rutgers, TRC Companies Inc., Holcim, and TGS.

The objective of this project is to establish a carbon management (CM) hub focused on developing carbon capture and storage (CCS) infrastructure at a geological storage complex in the north-central Anadarko Basin (Canadian Counties) by (1) identifying key technical knowledge gaps, (2) facilitating data acquisition, sharing, and analysis to close the gaps, (3) evaluating regional infrastructure, and promoting (4) technology transfer, and (5) public engagement and support. The project is built on intellectual and social products of the previously funded Southeast Regional Carbon Sequestration Partnership (SECARB) and channels public engagement through ongoing educational efforts such as the Professional Master of Science Program at Oklahoma State University (OSU), which, in association with industry and professional society partners, aspires to create a “carbon-ready” workforce.

CarbonSAFE Eos is devoted to carbon dioxide (CO₂) removal and promoting clean energy deployment in Colorado. The objective of this project is to progress development of a large storage site capable of holding at least 50 million tonnes of CO₂ over 30 years, and to incorporate principles of consent-based siting and two-way engagement for development planning. The project is acquiring 3D seismic data and drilling stratigraphic test wells in two locations to establish storage and prove up the sequestration fairway. These technical results will be overlain by insight from landowner and community engagement to allow for incorporation of landowner preferences to plan for operations most amenable to stakeholders. The project includes seismic data collection across both locations and the first test well at Chico Basin Ranch, as well as efforts to build strong developer-community relationships, increasing understanding of the social and economic development needs of the Pueblo region, and how carbon management can support further economic opportunities. The project's two test wells at Chico Basin Ranch and Brett Gray Ranch, and considerable work with specific impacted stakeholders will allow the project team to finalize the development plan, while establishing a robust framework for community benefits and engagement.

The Atlantic Coast CO₂ Emissions Storage Sink: Project ACCESS CarbonSAFE Phase II Project seeks to build on regional data sets that demonstrate that the subsurface within Miami‐Dade County, FL has the potential to store commercial volumes of CO₂ safely, permanently, and economically. The primary target reservoirs for the CO₂ storage complex are the deep Cedar Keys/Lawson and Dollar Bay carbonates located within the South Florida Basin, central Miami‐Dade County. These deep saline reservoirs are beneath a confining system encompassing at least 1,500 ft of anhydrite and other low-permeability sediments. Project ACCESS will acquire and process approximately 12 line-miles of 2D seismic data to ensure geologic rigor, as well as a shallow resistivity survey (karst identification), and then drill a deep stratigraphic test well to confirm the geological properties of the confining system and saline reservoirs within the storage complex. The geological data will be incorporated into numerical models to establish the areal extent of the CO₂ injection and help design the storage site and its monitoring system. The goal is to establish the foundation for a commercial scale geologic storage complex for CO₂ captured from Titan’s Pennsuco Cement Plant and surrounding industrial sources of CO₂ located in Miami‐Dade County, Florida.

The Sweetwater Carbon Storage Hub project is meeting CarbonSAFE Phase III project objectives through the completion of detailed carbon dioxide (CO₂) storage facility characterization and all necessary permitting for a commercial-scale, secure, geological CO₂ storage complex in the Greater Green River Basin of southwestern Wyoming. The scope of work includes a CO₂ Sources Feasibility Study; a Pipeline Front End Engineering and Design (FEED) study; a Storage Field Development Plan; and a risk assessment and mitigation plan, which will continue to be actively updated throughout the project life cycle. The project is investigating subsurface conditions and surface environment of the CO₂ storage complex. The eventual integrated commercial-scale CO₂ capture, transport, and storage hub will capture and store CO₂ from the largest proposed direct air capture (DAC) facility in the Rocky Mountains and one of the nation’s largest trona (soda ash) mines. In the project’s ideal and fully realized state the hub facility will accept CO₂ from more sources and expand the storage field to include more injection wells. This will yield economies of scale and reduce risk by following a proven hub model.

An Underground Injection Control (UIC) Class VI application for the commercial Carbon TerraVault III (CTV III) Storage Project is currently in process with the Environmental Protection Agency (EPA). This CarbonSAFE project will support the commercial-scale CTV III Storage Project by performing a comprehensive geologic characterization, develop a community benefits approach that addresses community needs and ensures transparency, and perform risk assessments, feasibility studies and technoeconomic studies of the project’s technical and non-technical challenges. A stratigraphic well will be drilled, and a comprehensive well logging campaign will be conducted. Field and laboratory studies will include coring, hydrologic testing, pressure profiling, and a variety of analyses of the subsurface media. The acquired data will be used to generate and validate subsurface models, develop reliable injection simulations, generate preliminary risk assessments, risk mitigation strategies, and long-term monitoring plans, and satisfy pre-operational testing requirements for the UIC Class VI permit application. An injection scenario analyses will be conducted to validate the viability of safely storing a minimum of 71 million metric tons of carbon dioxide over a 30-year period and determine the footprint of the predicted pressure front.

The Permian Regional Carbon Sequestration Hub Project is a feasibility study for the development of a carbon dioxide (CO₂) storage hub to serve the Southern Delaware Basin in Ward, Winkler, Reeves, and Loving Counties, Texas. The study is utilizing existing data to characterize targeted Ordovician-Devonian geologic formations for CO₂ storage that have an estimated storage resource of 75,000,000 metric tons of CO₂. The project is developing a detailed characterization of the targeted geologic storage complex, conducting a preliminary risk assessment including CO₂ source assessment, preparing and inventorying the relevant data that will support the Environmental Protection Agency (EPA) Underground Injection Control (UIC) Class VI-Wells used for Geologic Sequestration of Carbon Dioxide, Authorization to Construct Permit application (UIC Class VI Permit Application), developing an integrated assessment of project feasibility, and pursuing community outreach efforts.

The objective of the Magnolia Sequestration project is to advance the commerciality of carbon capture and storage (CCS) in Louisiana while supporting diversity, equity, inclusion, and accessibility (DEIA); disadvantaged communities; and environmental justice communities. The project plans to complete detailed site characterization, including a water analysis well and performing a 3D seismic survey. Additionally, the Magnolia Sequestration project will conduct a pipeline front-end engineering design (FEED) study, perform risk assessment of the storage complex, prepare storage field development plans, and advance community outreach and engagement.

This project is determining the feasibility of an integrated carbon storage project in central Mississippi. The project objective is to advance the commerciality of carbon capture and storage (CCS) while supporting diversity, equity, inclusion, and accessibility (DEIA); disadvantaged communities; and environmental justice communities. The project team plans to complete detailed site characterization, including drilling a stratigraphic test well and analyzing site geology. Additionally, the project will model the storage reservoir, perform a risk assessment, conduct public outreach and engagement, and develop the needed plans to draft an Underground Injection Control (UIC) Class VI permit.

The Texas Louisiana Carbon Management Community (TXLACMC) project is providing stakeholders in the fossil-fuel heavy, industrial corridor hub of Texas and Louisiana with crucial information about carbon capture and storage (CCS) to help bridge cost, environmental, and public education-awareness knowledge gaps. Leveraging the standing of universities as trusted local institutions with established relationships with their respective communities, the University of Texas at Austin, Texas A&M Corpus Christi, Texas A&M Kingsville, University of Houston, Lamar University, and Louisiana State University are utilizing their collective programs to relay this crucial CCS information. By establishing and developing a stakeholder community, this project is accelerating the situationally appropriate deployment of CCS as an emissions mitigation option for dozens of large volume industrial and power sector carbon dioxide (CO₂) emissions sources in the area. TXLACMC is uniting capture and storage projects in the Texas-Louisiana industrial corridor for cross-project information transfer on all key planning and development elements for successful regional CCS implementation.

University of Alaska Fairbanks (UAF) is determining the feasibility of developing a commercial-scale carbon dioxide (CO₂) geologic storage complex in the northern shore of the Cook Inlet Basin, Alaska. The safety and economic viability of the complex will be determined by: (1) conducting a 2D seismic survey and using modeling techniques to help characterize the storage site; (2) conducting risk assessments of technical and non-technical risks; (3) developing a plan for subsequent detailed site characterization and permitting documents necessary to construct and operate a commercial geologic storage facility; (4) conducting technical and economic analysis evaluation of the entire proposed CO₂ storage scenario; (5) identifying community benefits and impacts of the proposed research; and (6) implementing regional-specific plans to engage communities and stakeholders. Potential CO₂ sources include a proposed dual-fuel capable power generation plant located at the Flatlands Energy Corporation site and two existing natural gas fired power plants operated by the Chugach Electric Association.

The New Mexico Institute of Mining and Technology (NMT) is performing a comprehensive commercial-scale site characterization study at three proposed storage sites within the San Juan Basin in northwest New Mexico to facilitate the development of the Four Corners Carbon Storage Hub. Characterization requires performing 2D and 3D seismic surveys, re-entering an existing acid gas injection well, and drilling two new stratigraphic test wells. Data obtained from the geologic characterization study and environmental analysis will be used to verify that each proposed site can securely store a minimum of 50 million metric tons (MMT) of carbon dioxide (CO₂) in saline aquifers over a 30-year period. The project is preparing Environmental Protection Agency Underground Injection Control Class VI permit applications for submission and approval, for each storage location. The project is also submitting an Environmental Information Volume and working with the U.S. Department of Energy National Environmental Policy Act office to issue either an Environmental Assessment or Environmental Impact Statement.

BKV dCarbon High West is assessing the technical, economic, environmental, and community-level feasibility of utilizing barges to transport carbon dioxide (CO₂) to the High West carbon sequestration site in southeastern Louisiana. The project plans to complete a Front-End Engineering and Design (FEED) study that looks at various possible emission sources of CO₂ within 100 miles of the sequestration site and identifies optimal locations for loading, unloading, and storage infrastructure including the existing pipeline transportation network. The study is looking to aggregate at least one million tons of CO₂ per year for transport and storage from the Baton Rouge area and one million tons of CO₂ per year for transport and storage from the combined Pascagoula and Mobile areas.

ZuCO2 Transport (ZuCO2) is assessing feasibility of kick-starting an affordable maritime carbon dioxide (CO₂) transportation hub that links California’s geologic storage resources in the Central Valley to captured CO₂ sources in California, Oregon, and Washington via tugboats and barges capable of navigating near-coastal and inland waters. The project plans to complete a Front-End Engineering and Design (FEED) study and other technical and non-technical activities to examine the engineering, business, regulatory, workforce details and community impacts of starting and implementing the barge CO₂ transport system. Initial estimates indicate four barges could accommodate transport of one million metric tons/year of CO₂ based on an average estimated transit distance.

Advanced Resources International is determining the feasibility of developing a commercial-scale carbon dioxide (CO₂) geologic storage hub near Monkey Island, Louisiana. The storage portion of the project will be the first developed on offshore Louisiana state lands. The safety and economic viability of the hub are determined by: (1) acquiring existing commercial seismic data covering areas of the prospective CO₂ storage; (2) drilling an onshore stratigraphic test well to obtain log and core data required to inform geologic and reservoir models; (3) conducting risk assessments of technical and non-technical risks; and (4) ensuring continuous community engagement and partnership. By its conclusion, the project plans to submit NEPA Documentation, and prepare a Geologic Catalog of Materials, a Storage Field Development Plan, and a CO₂ Pipeline FEED Study.

The Williams Echo Springs CarbonSAFE Storage Complex Feasibility Study is assessing the technical and non-technical aspects of an integrated carbon capture and storage (CCS) project at a site adjacent to the Echo Springs Gas Plant in Carbon County, Wyoming. Planned characterization includes permitting and drilling a deep, approximately 12,000 feet below ground surface, stratigraphic test well and interpret the resulting data, which will provide the foundational information needed to determine the site’s suitability for future CarbonSAFE phases and commercial operations at the proposed carbon dioxide (CO₂) storage complex.