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This report consists of a 2012 press release announcing the start of CO 2 injection in Alabama and describes the Southern States Energy Board and SECARB.
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The Southeast Carbon Sequestration Partnership Phase III Anthropogenic Test at Citronelle Field is one of the United States’ largest demonstrations of CO 2 capture, transportation, injection, storage and monitoring using CO 2 derived from a coal-fired electric generating unit. This report summarizes the background and initial injection phase groundwater and soil flux monitoring results.
The Southeast Carbon Sequestration Partnership Phase III Anthropogenic Test at Citronelle Field is the United States’ largest prototype of commercial CO 2 capture from a coal-fired power station and transportation, injection, storage and monitoring. This report details the results of the second and third year of injection monitoring results for the Anthropogenic Test. Monitoring methods include both direct and indirect measurements. The Class V Experimental Permit requires extensive monitoring of injected CO 2 at the surface and at deep and shallow depths. The safety, integrity and information objectives of the CO 2 monitoring plan are in place to: (1) create and sustain wellbore integrity; (2) assure safe CO 2 injection operations; 3) verify the location and migration of the injected CO 2 plume; and (4) monitor for any CO 2 leakage. A robust suite of monitoring approaches are utilized for the insitu monitoring and include, pressure monitoring, various seismic surveys, pulsed neutron logging, reservoir fluid sampling and injection surveys. Data and observations collected using these monitoring methods will be used in the numerical model to inform the post-injection site care monitoring plan. This report describes actions pertaining to in situ monitoring at the Anthropogenic Test Site that were undertaken during the period of October 2013 to January 2015. This report details the results of the second and third year of injection monitoring results for the Anthropogenic Test. Work Product 9.2.2.b details the shallow monitoring results for 2014. CO 2 injection operations began on August 20, 2012 and terminated on September 1st 2014.
The Southeast Carbon Sequestration Partnership Phase III Anthropogenic Test at Citronelle Field is the United States’ largest CO 2 capture and transportation, injection, storage and monitoring project using CO 2 derived from a coal-fired power station. The project represents a U.S. Department of Energy research and development initiative designed to demonstrate deep underground injection and containment of 100,000 tonnes or more of anthropogenic-source CO 2 . A series of reservoir modeling runs will be performed during the pre-injection, injection, and post-injection phases of the project and will be used to predict plume migration and areal extent. Pressure, temperature, and downhole measurements (seismic, fluid and logging), all data collected as a part of the monitoring program, are utilized as reservoir performance parameters to tune the existing geophysical and geochemical simulation models. The ability to represent site injection activities with the produced detailed simulation models lend credence to long-term forecasts of CO 2 fate and the progress of the CO 2 plume. This report provides an assessment of the simulation model results for CO 2 injection at the Citronelle Anthropogenic Test site from the period of August 20, 2012 to August 31, 2013.
The Southeast Carbon Sequestration Partnership Phase III Anthropogenic Test at Citronelle Field is the United States’ largest CO 2 capture and transportation, injection, storage and monitoring project using CO 2 derived from a coal-fired power station. The project represents a U.S. Department of Energy research and development initiative designed to demonstrate deep underground injection and containment of 100,000 tonnes or more of anthropogenic-source CO 2 . A series of reservoir modeling runs will be performed during the pre-injection, injection, and post-injection phases of the project and will be used to predict plume migration and areal extent. Pressure, temperature, and downhole measurements (seismic, fluid and logging), all data collected as a part of the monitoring program, are utilized as reservoir performance parameters to tune the existing geophysical and geochemical simulation models.
The Southeast Carbon Sequestration Partnership (SECARB) Anthropogenic Test is a U.S. Department of Energy funded fully integrated carbon capture and storage initiative designed to demonstrate deep underground injection and containment of anthropogenic CO 2 sourced from Alabama Power’s Plant Barry. From August 20, 2012 to September 1, 2014, a total of 114,014 metric tonnes of CO 2 were transported via pipeline from Plant Barry and stored in a saline aquifer under a portion of the Citronelle Field operated by Denbury Onshore, LLC near Citronelle, Alabama. A major component of this project was to test and develop techniques to monitor, verify and account (MVA) for the CO 2 stored in the aquifer by the project. A suite of technologies were applied and developed to demonstrate non-endangerment of underground sources of drinking water (USDW’s) and to ensure that CO2 does not migrate out of intended zones within the subsurface. This involved several levels of monitoring: 1) Surface monitoring, 2) shallow groundwater monitoring, 3) deep reservoir monitoring and experimental MVA activities. Numerical models were developed to determine the project’s Area of Review (AoR) and to investigate the simulated advancement of the CO 2 plume through the subsurface aquifer for 30 years after the end of injection. An initial baseline area of review of 1,700 ft. was established. The key results demonstrating non-endangerment of USDW’s are presented.
This report summarizes the end of field activities at the SECARB Phase III early test at Cranfield. Timing of the activities was coordinated with Denbury and several project teams, and Sandia Technologies.
The D 9-7#2 is a UIC Class V injection well (ADEM permit number ALSI9949664), located in Citronelle Oil Field, Citronelle Alabama. The purpose of the well was to inject CO2 into the upper Paluxy formation in an experiment to investigate the potential underground CO2 storage in a deep saline reservoir. A total of 114,104 metric tonnes of CO2 were injected through the D 9-7#2 between August 20, 2012 and September 1, 2014. A minimum three-year post injection site care period began on September 1, 2014. This report summarizes the permanent plugging and abandonment of the D-9-7#2 well. Following the demonstration of CO2 containment and non-endangerment (ref acknowledgement letter from ADEM dated September 27, 2017), Denbury developed a plugging and abandonment (PA) plan for the well. This plan was approved by the Alabama Oil and Gas Board and complies with Denbury’s environmental, health and safety guidelines. The D-9-7#2 well was spud in December 2011 and was drilled to a total depth of 11,790 ft. Prior to the well plugging operations a cement retainer was set in the well casing at 9,336 feet to isolate the injection zone and a 10-feet cement plug was set at 10,790 feet to isolate the oil reservoir, the ‘Donovan’ formation which lies underneath the Paluxy.
Two temporarily abandoned Citronelle Oil Field wells (D 4-13 and D 4-14) located up-dip from the D 9- 7#2 injection well (approximately 3,500 feet away) and outside of the area of review (Figure 1) were designated to be used for the monitoring activities associated with the SECARB Anthropogenic Test. Both wells were recompleted prior to the project, which included perforating the D 4-14 within the injection zone and the D 4-13 above the proposed confining unit. The D-4-13 well provides above-zone pressure monitoring in a perforated interval from 9,186 feet to 9,188 feet, with the gauge landing nipple at 9,111 feet. In-zone pressure monitoring occurs in the D-4- 14, perforated from 9,420 feet to 9,422 feet. The gauge landing nipple was set at 9,375 ft. Following the completion of the project These wells were converted back to their original condition for oilfield operations.
This report summarizes the revisions made after attainment of project metrics of monitoring 1.5 million metric tons stored which occurred at 1 ½ years and after the end of the period of accelerated injection rate (February 2011) to reach project metrics. Denbury continues downdip injection because of its impact on production, but has modified the rate of injection to meet its EOR objectives. Therefore this project will not have a post-injection “closure” period. Injected CO 2 is being recycled and the flow field is substantively controlled by production. However, a period of observation of this long duration storage has value to the program in terms of showing no impact on near-surface environments and monitoring any changes in the reservoir over the long term. In addition, observations made during the first two years of injection have raised a number of significant questions that can be addressed during the next stages of research. Lastly, budget readjustment is needed, as some tasks have gone over budget and some have been completed under budget, leaving some opportunities to address remaining issues. This report provides an overview of the revisions and supplements proposed to the modeling and monitoring plan to complete the project.
This is a description of a compilation of the datasets compiled by the Gulf Coast Carbon Center SECARB project, Bureau of Economic Geology, The University of Texas at Austin. Datasets are categorized by data types with a description of each dataset. The datasets are on a separate DVD.
In this paper, we compare 4D seismic interpretations of CO 2 plume evolution with fluid flow numerical simulation results for the SECARB Early test at Cranfield, Mississippi. Historic pressure trends, oil and gas production rates and current CO 2 -EOR production data from the field were history matched and tuned model used for predictive simulations. For CO 2 -EOR operations the tuned model results showing CO 2 plume distribution and CO 2 first arrival (break-through) times in production wells were compared to the available field data. Reasonable matches were observed with breakthrough times. However 4D seismic interpretations of saturated region distributions and simulation results mismatch in some significant ways, likely showing limitations in 4D seismic interpretations for Cranfield. The tuned model then used to predict reservoir response and storage capacity in different field development scenarios. We compared hypothetical scenarios where the operator decided to transition into CO 2 injection without oil production (CO 2 -EORT) when oil production is not economical versus a scenario of continuing with CO 2 -EOR. Our results show that CO 2 -EOR can store more CO 2 and operations will last longer whereas if switched to CO 2 -EORT field has to be abandoned earlier because of out-of-area movement of the CO 2 plume. However, the amount of CO2 stored per year during the operational period is larger for CO 2 -EORT.
Objectives of the shallow groundwater study at the Cranfield site since 2008, as a part of the SECARB Phase III early test, were to 1) assess potential impacts of CO 2 leakage on groundwater quality; and 2) test and develop monitoring technologies for CO 2 leakage detection. The study did not intend to seek CO2 leakage signals via monitoring groundwater chemistry in the Cranfield shallow aquifer. Instead, quarterly or semi-annually groundwater sampling from the shallow aquifer was used to characterize spatial and temporal variations in geochemical parameters because CO 2 injection into the deep reservoir started in 2008.
Aging coal-fired power plants are retiring across the United States. Researchers at Pacific Northwest National Laboratory studied coal-fired power plant decommissioning business models to support program development for the Department of Energy’s Office of Energy Efficiency & Renewable Energy (EERE) to engage with communities affected by power plant retirement processes. Evaluating and reducing the impact on coal-dependent communities from phasing out coal production is a crucial piece of nationwide economic development and community-directed engagement in the clean energy future. This report describes the steps in the typical coal-fired power plant decommissioning process, including analysis of the following key factors: Drivers including policy and regulations, competition with other fuels, and corporate responsibility goals; Types of coal plant decommissioning including plant retirement without full decommissioning, repurposing with fuel switch, redeveloping to utilize existing transmission, and decommissioning and repurposing with other commercial activities; and, Costs of coal plant decommissioning, including variations across regulated and deregulated markets and the funding resources to support decommissioning activities. The details described in this report relied heavily on the availability of local news reports and communications regarding plant retirements, as the researchers identified a lack of formal literature surrounding business models for coal plant decommissioning and a need for a more robust source material collection. In addition, a lack of oversight entities responsible for decommissioning processes may have led to this shortfall of information. Future research regarding coal plant decommissioning can include quantitative studies on power plant retirement drivers, procedures, and costs, qualitative assessments on affects decommissioning has on surrounding communities, investors, and other stakeholders, and identifying best practices to engage community stakeholders in the decommissioning process.