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Facilitating CCS Business Planning by Extending the Functionality of the SimCCS Integrated System Model
The application of integrated system models for evaluating carbon capture and storage technology has expanded steadily over the past few years. To date, such models have focused largely on hypothetical scenarios of complex source-sink matching involving numerous large-scale CO 2 emitters, and high-volume, continuous reservoirs such as deep saline formations to function as geologic sinks for carbon storage. Though these models have provided unique insight on the potential costs and feasibility of deploying complex networks of integrated infrastructure, there remains a pressing need to translate such insight to the business community if this technology is to ever achieve a truly meaningful impact in greenhouse gas mitigation. Here, we present a new integrated system modelling tool termed SimCCUS aimed at providing crucial decision support for businesses by extending the functionality of a previously developed model called SimCCS. The primary innovation of the SimCCUS tool development is the incorporation of stacked geological reservoir systems with explicit consideration of processes and costs associated with the operation of multiple CO 2 utilization and storage targets from a single geographic location. In such locations provide significant efficiencies through economies of scale, effectively minimizing CO 2 storage costs while simultaneously maximizing revenue streams via the utilization of CO 2 as a commodity for enhanced hydrocarbon recovery.
Plant-wide modeling of an indirect coal–biomass to liquids (CBTL) plant with CO2 capture and storage (CCS)
Not Available
Combining multiple lower-fidelity models for emulating complex model responses for CCS environmental risk assessment
Numerical modeling is essential to support natural resource management and environmental policy-making. In the context of CO 2 geological sequestration, these models are indispensible parts of risk assessment tools. However, because of increasing complexity, modern numerical models require a great computational effort, which in some cases may be infeasible. An increasingly popular approach to overcome computational limitations is the use of surrogate models. This paper presents a new surrogate modeling approach to reduce the computational cost of running a complex, high-fidelity model. The approach is based on the simplification the high-fidelity model into computationally efficient, lower-fidelity models and on linking them with a mathematical function (linking function) that addresses the discrepancies between outputs from models with different levels of fidelity. The resulting linking function model, which can be developed with small computational effort, can be efficiently used in numerical applications where multiple runs of the original high-fidelity model are required, such as for uncertainty quantification or sensitivity analysis. The proposed approach was then applied to the development of a reduced order model for the prediction of groundwater quality impacts from CO 2 and brine leakage for the National Risk Assessment Partnership (NRAP) project.
Using microseismic data recorded at the Weyburn CCS-EOR site to assess the likelihood of induced seismic activity
Not Available
A cash flow model of an integrated industrial CCS-EOR project in a petrochemical corridor: A case study in Louisiana
Petroleum refineries and petrochemical plants are major CO 2 sources, however, they are also significant capital and employment assets that are unlikely to be replaced in the near term. As a result, nations and states that are interested in reducing the carbon intensity of their economies will need to find ways to reduce the emissions of their existing industrial capacity. Industrial carbon capture provides one potential mechanism for reducing the carbon intensity of existing industrial facilities, however, an economically feasible capture system requires that the captured CO 2 be integrated into a system of transport and storage with income generated either through tax credits, enhanced oil recovery (EOR), or both. Here, we present a cash-flow model of an integrated system with industrial capture, pipeline transport, and EOR, and we parameterize the model with data from Louisiana. Given a 50/bbl oil price, an integrated capture, transport and EOR system that uses ethylene oxide production, ammonia production, or natural gas processing as sources is predicted to have a net present value of about $500 million; hydrogen-based capture has a cash flow of -214 given the same assumptions. Further, we find that the recent 45Q Tax Credit expansion has a positive impact on the cash flow of the system but does not change the overall profitability of the systems under the specified assumptions such that without the tax credits natural gas processing, ammonia production and ethylene oxide production-based capture systems remain cost-effective, while hydrogen-based capture remains unprofitable with or without the tax credit.
Guidelines for the selection of corrosion resistant alloys for CCS and CCUS injection wells
Not provided.
Relocating microseismicity from downhole monitoring of the Decatur CCS site using a modified double-difference algorithm
SUMMARY The injection of CO2 at the Decatur carbon capture and storage site has generated significant microseismic activity, which occurs in distinct spatial clusters up to approximately 2.2 km from the primary injection well. Accurate and precise event locations are vital for the characterization of the microseismicity to help understand the reservoir response to the CO2 injection, whilst enabling the identification of minor faults and fractures below the resolution of conventional active seismic imaging. However, microseismic monitoring of fluid injection sites, such as Decatur, is often performed using a network of borehole sensors often from a single well. While these downhole sensors have excellent detection capabilities, their poor azimuthal coverage limits the ability to precisely determine event locations. We have developed a modified double-difference relocation algorithm suitable for both 1-D and 3-D velocity models, and which incorporates differential back azimuth observations to allow the benefits of the original double-difference algorithm to be applicable to a downhole microseismic monitoring setting. Applying the modified double-difference algorithm to the microseismicity at Decatur, we have successfully relocated 4293 events. The relocation included over 59 million observations for 757 285 event pairs, split across seven geographic regions. Despite the majority of observations being recorded in only two boreholes, with an almost identical azimuthal coverage, the results have shown to be reliable with significantly reduced residuals and low uncertainties associated with the final locations. We have analysed the residuals in terms of their association with each geographic region, data type, station and individual events, to fully appreciate their influence in the inversion and the fit of the data to the final set of event locations. For each region, the relocated seismicity has become less diffuse with improved clustering, and with newly visible linear features often orientated in a NE–SW direction. These results show the potential improvements that can be made to microseismic event locations recorded by a borehole network with a limited and variable azimuthal distribution.
Access Capabilities Through Ccs Communications Protocol (acccs)
AcCCS is a collection of scripts that leverage open-source code, off-the-shelf hardware, and published protocol specifications to create a flexible and inexpensive test and evaluation device for the Electric Vehicle industry. AcCCS is capable of emulating either an Electric Vehicle (EV) or Electric Vehicle Supply Equipment (EVSE). It provides a flexible set of Python scripts to test and evaluate the various communication protocols between the Electric Vehicle Communication Controller (EVCC) and Supply Equipment Communication Controller (SECC). This capability is useful for cybersecurity researchers, automotive OEMs, and EVSE manufactures.
Permitting A Coal-Fired 4-MMt/yr CCS Project in North Dakota, USA
Paper presented at 16th International Conference on Greenhouse Gas Control Technologies (GHGT-16), October 23–27, 2022, Lyon, France. As part of the U.S. Department of Energy’s CarbonSAFE Program, the Energy & Environmental Research Center (EERC), in partnership with Minnkota Power Cooperative, Inc. (Minnkota), conducted commercial-scale site characterization and permitting of two deep saline formations for the geologic storage of anthropogenic CO 2 emissions. Captured as part of Minnkota’s Tundra SGS (secure geologic storage) project, these storage horizons would collectively and permanently store an annual average of 4 million metric tons (MMt) of CO 2 .
Technical - Coal Gasification Technologies Subtopic d: Hybrid Integrated Concepts for IGCC (with CCS) and Non-Biomass Renewable Energy (e.g. Solar, Wind)
Currently in the United States, there are more than five hundred coal-fired power plants producing a total of 1.5 billion tons of carbon dioxide emissions per year. 1 The total annual CO 2 sequestration and transportation cost for the five hundred coal-fired power plants in the United States can surmount $98.6 billion per year. 2 Therefore, power generation technologies that utilize domestic coal resources while reducing carbon emissions are heavily sought in order to maintain energy security while decreasing greenhouse gas (GHG) emissions. Coal gasification can convert domestic coal resources into syngas which can be used in a combined cycle power block to generate power while reducing GHG emissions. In addition, carbon capture and sequestration technologies are more economical in gasification processes than in direct combustion, which reduces capital and maintenance costs for power generation. Under a Department of Energy (DOE) Small Business Innovative Research (SBIR) program entitled “Hybrid Solar Coal Gasifier”, (Contract number: DE-SC0008355) Advanced Cooling Technologies, Inc. (ACT) designed and developed an innovative, indirectly heated, fuel flexible, heat pipe driven gasification reactor that can be hybridized with concentrated solar power (CSP) towers to further reduce the carbon emissions over current gasification processes. This hybridization of solar and coal gasification technologies helps to bridge the transition from traditional fossil fuel power generation towards systems based on more sustainable, renewable energy resources. The nine month program started on May 28, 2012 and ended March 27, 2013.
CCS Project Permit Acquisition Protocols
Geologic carbon storage projects require a vast range of permits prior to deployment. These include land-access permits, drilling permits, seismic survey permits, underground injection control permits, and any number of local and state permits, depending on the location of the project. For the “Characterization of Most Promising Sequestration Formations in the Rocky Mountain Region” (RMCCS) project in particular, critical permits included site access permits, seismic survey permits, and drilling permits for the characterization well. Permits for these and other activities were acquired either prior to or during the project.
CCS-6 Recruiting Slide
This document is a job announcement for statisticians at LANL.
Assessment of the Area of Review and Leakage Impact for Site 7 using the NRAP-IAM-CCS Tool, Northern Michigan Basin-CarbonSAFE Phase 1 Pre-Feasibility Study
U.S. Environmental Protection Agency’s (EPA’s) Class VI regulations require owners or operators of carbon storage projects to determine an Area of Review (AoR) representative of project risk to underground sources of drinking water (USDWs). The AoR is an estimate of the project footprint and is used to develop monitoring plans to ensure protection of USDWs. In this syudy, the NRAP-IAM-CS software tool was applied to estimate the AoR and the leakage potential of legacy wells located within the AoR to impact groundwater quality at a carbon storage screening site for the NMB-CS, Phase 1 project. The NRAP-IAM-CS is a science-based toolset developed by the U.S. Department of Energy for quantitative risk assessment of geologic sequestration of carbon dioxide (CO 2 ) (Pawar et al., 2016). The toolset adopts a stochastic approach in which predictions include site uncertainties using storage reservoir, leakage scenario, and shallow groundwater impact reduced order models (ROMs). Risk-based analysis done using the NRAP-IAM-CS yielded an AoR that was comparable to estimates defined by the critical pressure needed move fluid from the reservoir to the overlying USDW through an open wellbore. The risk-based AoR was slightly smaller than that based on the critical pressure (234 km 2 compared to 269 km 2 ), because small fluxes did not impact groundwater quality. Leakage from two legacy wells located within the AoR should not impact groundwater quality over the 30-year injection period. Legacy Well 1 penetrates the simulated CO 2 plume and would require a permeability of 5 x 10 -12 m 2 (~5 Darcy) to impact groundwater quality after about 20 years of injection. Legacy Well 2 falls outside of the CO 2 plume footprint, where reservoir pressures are too small to generate large enough leakage flux to change groundwater quality even with well permeabilities as high as 5 x 10 -11 m 2 (~50 Darcy). This work represents one of the first applications of the NRAP toolset for the screening of potential CO 2 storage sites. The toolset provides a risk-based method of evaluating the AoR and the impact of CO 2 or brine leakage through legacy wells. The following recommendations will strengthen the use of probabilistic assessments for site selection and permitting of Class VI CO 2 injection wells.