Assessing the Risks and Opportunities of Dual-purpose CO2 Injection for Enhanced Oil Recovery (EOR) and Long-term Storage: Implications for U.S. Energy Security and Economic Growth

Best Practice for Transitioning from Carbon Dioxide (CO2) Enhanced Oil Recovery EOR to CO2 Storage

The article explores the potential of CO2 injection technology for enhanced oil recovery (EOR) and simultaneous reduction of carbon emissions through storage in oil reservoirs and aquifers. The study focuses on 23 oil fields on the Norwegian Continental Shelf, identified as promising candidates for implementing this technology. The model used in the research assesses the economic and technical feasibility of CO2 injection, along with the integration of EOR and long-term carbon storage. The primary goal is to demonstrate that injecting 70 million tons of CO2 annually over 40 years can result in an additional oil recovery of 5.9%-7.6% of the original oil in place, equivalent to 276-351 million cubic meters. Excess CO2 can be stored in aquifers, further contributing to the reduction of carbon emissions. The article outlines key aspects of the study, including economic and technical parameters, such as costs associated with CO2 transportation, storage, and drilling of new wells, as well as various oil and CO2 price scenarios. The environmental benefits of the project are highlighted, showing that the significant CO2 retained in oil reservoirs and aquifers compensates for emissions from the combustion of recovered oil. The study also discusses the features of the model, including scenarios for continuous CO2 injection and considerations of infrastructure costs. The article emphasizes the importance of developing and implementing such projects in the context of global climate change mitigation efforts and points to the significant potential of CO2 injection technology for the oil industry. The aim of this article is to evaluate the feasibility and potential benefits of large-scale CO2 injection for enhanced oil recovery (EOR) and long-term carbon storage in oil fields and aquifers. The study seeks to demonstrate how CO2 injection can increase oil recovery rates while simultaneously reducing carbon emissions, providing a comprehensive technical-economic assessment of the process. Through the analysis of 23 oil fields on the Norwegian Continental Shelf, the article aims to present the economic, environmental, and operational advantages of integrating CO2 storage with EOR operations.

Interest in CCS project development is accelerating in SE Asia, driven by the need to monetize emission-intensive assets in the region while complying with increasingly ambitious GHG emissions targets. Depleted hydrocarbon fields represent an attractive storage option for early CCS project due the enhanced understanding of the reservoir, its dynamic behavior, and proven storage capability. Re-use of existing infrastructure also presents the potential to reduce both project costs and time to first injection, however, these brownfield sites also carry significant risk to the long-term, safe containment of injected CO2 through risk of leakage via legacy wells. A methodology is presented in this paper to investigate the risk-reward balance of developing a depleted gas field as a storage site in the Gulf of Thailand. A screening process to assess all abandoned, suspended, and active wells is used to identify wells with re-use potential as CO2 injectors or CO2 plume monitoring wells, and those which represent a leakage risk to the project. A set of legacy well risk identifiers is generated for the field based on well construction records, descriptions of current well barriers, well utilization history, and current best practice guidelines. Southeast Asia has significant remaining reserves of oil and gas, and coal, and an active liquefied natural gas (LNG) export industry. The region's energy demand is increasing rapidly and is forecast to continue to grow over the next decades (World Economic Forum, 2019). To date, fossil fuels have supplied nearly 90% of this growth in the demand for energy in the region (IEA, 2021). To meet this growing energy demand, several new gas projects are under development across Southeast Asia, but many of these are associated with high CO2 gas fields where the produced gas contains significant (up to 70% by volume) CO2 (GCCSI, 2020). In Thailand, where nearly 94% of the primary energy is met by fossil fuels (BP Statistical Review, 2022), the energy sector represents the biggest contributor (74% in 2013) to the country's greenhouse gas emissions (GHG; UNFCCC, 2020). However, as per the nationally determined contribution to the United Nations Framework Convention on Climate Change (UNFCCC), Thailand intends to reduce its GHG emissions by at least 20% from projected business as usual levels by the year 2030 (UNFCCC, 2020). Carbon capture and storage (CCS) represents one option to help meet this increased demand in fossil energy while also reducing GHG emissions. An approach which is gaining traction across the region is to utilize the high concentrations of CO2 stripped out of the raw gas streams at gas processing plants and, instead of venting to atmosphere, the CO2 can be compressed, dehydrated, and transported to suitable long-term storage locations. Depleted oil and gas fields form an attractive opportunity for long-term storage of CO2 due to the wealth of both static and dynamic knowledge available from appraisal through production activities. Depleted fields also have the advantage that they have a working primary seal for hydrocarbons, which has been proven over geological time and so can be considered, in general, to carry low risk of leakage through geological means. Brownfield sites can, however, also represent a challenge to project success through an increased risk to the containment of the injected CO2 due to the presence of legacy wells. These existing wells represent a variable risk to containment depending on well age and type, well history, well design, and plug and abandonment methodology applied. This paper presents the outcomes of a CO2 storage feasibility study for a depleted gas-condensate field in the Gulf of Thailand. The main aims of the study were to:1) identify the project risk associated with the integrity of the field legacy wells, and 2) to evaluate the potential for well re-use for the CO2 injection project. Reusing an existing field offers new life to an otherwise end-of-life asset, inching towards decommissioning and site closure. As commercial scale CO2 storage in depleted hydrocarbon fields represents a ‘First of a Kind’ project, the feasibility study is designed to evaluate the current status of the field and surface facilities with respect to CO2 injection and long-term storage. As a feasibility study, the focus of the technical work was to identify any ‘showstoppers’ which might indicate that the selected site was not suitable for long-term CO2 storage and, if sufficient positive storage indicators were identified, to select the most appropriate options for progression into a Concept Selection study in which more detailed engineering studies will be completed.

The highly urbanized area around Los Angeles is dotted with oil fields and refineries. Oil wells perch in yards, parking lots, even schools. The Wilmington oil field, which stretches beneath much of the land between Los Angeles and its port, as well as for miles off the coast, supplies numerous local refineries that in recent years have shut down repeatedly during power outages. Restarting the facilities often causes clouds of odorous and potentially hazardous gas to be released. After a 3 October 2007 shutdown, for example, a ConocoPhillips refinery released a cloud of “yellow, metallic dust” containing what company representatives called “a mixture of iron, copper, nickel, aluminum, carbon, and other elements,” according to the local DailyBreeze.com news service.

Technology Focus Can enhanced oil recovery (EOR) contribute to CO2 abatement as part of a climate-change-mitigation program? EOR by use of CO2 is an important technique for increasing oil recovery. Carbon capture and storage (CCS) will be an increasingly important technique for reducing atmospheric emissions of CO2 as part of a climate-change-mitigation program. What role does EOR have in reducing CO2 emissions to the atmosphere and in supporting climate-change mitigation? It is clear that the two processes have very different objectives: EOR focuses on maximizing the amount of oil recovered, whereas CCS focuses on sequestration of CO2 for the long term. Most existing EOR projects use naturally occurring CO2, produced from subsurface traps especially for EOR. Rather than mitigating emissions, these projects contribute to global CO2 emissions. Clearly, this situation is not good for the climate. Other emerging EOR projects and future projects could use anthropogenic CO2 (i.e., CO2 from industrial sources). When the CO2 associated with the use of the EOR oil is taken into account along with the processing and emissions from CO2 recycling, EOR is a significant producer of greenhouse gas and not a CO2-abatement technique. However, EOR oil does have a lower emissions intensity than non-EOR oil, assuming that the CO2 is from anthropogenic sources. It would be much better, for example, to produce a barrel of EOR oil than a barrel of oil from oil sands. EOR has an important role to play in energy security, but from a global-climate perspective, it is not a CO2-abatement technique. CO2 Applications additional reading available at OnePetro: www.onepetro.org SPE 116661 • "Optimizing Injection Intervals in Vertical and Horizontal Wells for CO2 Sequestration" by Navanit Kumar, SPE, University of Texas at Austin, et al. SPE 119747 • "Thermodynamic Criteria and Final Results of WAG CO2 Injection in a Pilot Project in Croatia" by D. Novosel, INA-Naftaplin SPE 114553 • "Produced CO2 Storage Into Aquifer in an Offshore Field, Malaysia" by Dewanto Odeara Kartikasurja, SPE, Senergy Ltd.

In the pursuit of sustainable energy solutions and enhanced energy security, the integration of Carbon Capture and Storage (CCS) into exploration strategies emerges as a critical imperative. Geoscientists play a central role in this endeavor, leveraging their expertise to navigate the complexities of CCS implementation within exploration frameworks. This paper delves into the multifaceted landscape of CCS integration, elucidating its significance in mitigating greenhouse gas emissions and bolstering sustainability efforts. Through a comprehensive analysis of traditional exploration strategies, it underscores the compelling need to incorporate CCS methodologies to fortify sustainability objectives. Geoscientists, equipped with their specialized skill set, assume pivotal roles in driving CCS integration forward. Their proficiency in data analysis, coupled with an innate understanding of geological formations, enables them to chart pathways towards effective CCS deployment. Collaborative endeavors between geoscientists and diverse stakeholders further amplify the impact of CCS initiatives, fostering innovation and knowledge exchange within the energy sector. Drawing upon illuminating case studies, this paper examines successful instances of CCS integration in exploration projects, ranging from conventional offshore ventures to unconventional resource exploration. These case studies offer invaluable insights into the practical applications of geoscientific principles in shaping sustainable energy futures. Additionally, the paper explores emerging trends, future directions, and policy considerations aimed at fostering a conducive environment for CCS adoption within exploration strategies. This paper underscores the indispensable role of geoscientists at the vanguard of energy security and sustainability. By spearheading the integration of CCS in exploration strategies, geoscientists pave the way for a more resilient and environmentally responsible energy landscape.

CO2 resistant cement-zonal isolation technology dedicated to CO2 geological storage-provides an enduring solution to reducing well leakage risks in carbon capture and storage (CCS) and CO2 enhanced oil recovery (EOR) projects.CCS involves capturing CO2 from the major sources of concentrated emissions and injecting it into selected geological formations such as saline aquifers, depleted hydrocarbon reservoirs and unminable coal beds. CCS has the potential to make a critical contribution to reducing the amount of greenhouse gas released into the atmosphere as the most effective, safe, and low-cost long-term CO2 storage technology.One of the key requirements in CCS is long-term zonal isolation. Subsurface pressure and temperature changes can compromise the stability and integrity of the cement sheath around a CO2 injection well. Compromising well integrity can quickly lead to CO2 leakage at the surface, putting containment at risk. That's why the cement sheath used in the wellbore must be exceptionally durable and able to maintain its integrity for hundreds of years.Portland cement has been used successfully for decades in oil and gas well cementing. However, such cements are thermodynamically unstable in CO2-rich environments and degrade once exposed to CO2 in the presence of water. For this reason, compromised well integrity has been identified as the greatest risk factor for leakage from underground storage sites.CO2-resistant cement ensures lasting zonal isolation. In laboratory tests, the system proved highly resistant to CO2 attack, maintaining stable mechanical properties after exposure to simulated extreme injection/storage downhole conditions, including wet supercritical CO2 and water saturated with CO2. This cement system is 100% compatible with Portland cement and can be blended, mixed, and pumped using standard field equipment. It can be used for zonal isolation in new CO2 injection wells, or to plug and abandon existing CO2 injection/production wells at the end of a project.

The role of CO2 capture and storage in Saudi Arabia's energy future

One of the harms to climate brought about by anthropogenically instigated environmental change is the overabundance creation of CO2 because of industrialization. Research and development endeavors so far have been focused on the improvement of CCS (Carbon Capture and Sequestration), with the fundamental spotlight on the best way to eliminate CO2 from vent gases and how to cover it perpetually in deep aquifers or depleted oil and gas reservoirs to save the environment from the detrimental effects of CO2. At one side, the alarming situation due to excess emission of CO2 from industries has been bulled out and simultaneously, there is higher potential for CO2 in the depleted oil fields which can aid to the Enhanced Oil Recovery (EOR) through the prolonged CO2 injection in depleted oil fields. It is currently turning out to be certain that CCS technology could advance the utilization of fossil fuels than in any case recently thought. This paper discusses the integration of Carbon Capture and Sequestration (CCS) technology with the progressive strategy of Enhanced Oil Recovery (EOR). CCS includes various advances that can be utilized to catch CO2 from point sources. Countries that are badly affected by the harmful effects of global warming with depleting oil reserves in the very near future can be the most viable target of the CCS Project. The scope and potential of different techniques of CCS along with the opportunities and challenges and the real case scenarios happening in the world are discussed in detail. The economics, process cycle and case studies of this futuristic technology intend to give valuable insight to the implementation of this integrated technique to the prevalent depleting oil fields around the globe.

The challenges facing offshore CO2 enhanced oil recovery (EOR) and carbon capture and storage (CCS) projects are presented in this paper along with potential solutions based on the oil and gas (O&G) industry's CO2 EOR and CCS experience and technology as applied in a few offshore locations. Prospects for future offshore projects are also discussed based on the O&G industry's experience, technology, and best practices. These achievements are the result of a safe and successful 58-year history of well construction and operations in land-based, commercial CO2 EOR projects. Achieving CCS by injecting CO2 into saline formations or for EOR in mature oil reservoirs is a safe and effective method to reduce GHG (greenhouse gas) emissions. The IPCC has defined enhanced oil and gas recovery via CO2 injection as a recognized form of CCS. Using existing industry experience and technology developed over the past 58 years, CO2 injection into oil reservoirs for EOR has been safely and effectively applied in 18,077 active wells worldwide (17,112 in USA) according to the latest EOR survey (O&GJ, 2010). Production from natural gas reservoirs has also benefitted from CO2 injection in enhanced gas recovery (EGR) applications. Key results are summarized and major conclusions presented from studies by the American Petroleum Institute; Advanced Resources International; European Commission, DG-Joint Research Centre, Institute for Energy; Kinder Morgan; Norwegian Petroleum Directorate; Bellona Foundation; Norwegian University of Science and Technology; SINTEF Petroleum Research; and others. Conclusions from these studies point to the substantial value of current industry experience as a sound basis for offshore CCS applications. Offshore CCS/EOR may be more viable than onshore options for areas with high population densities, where offshore reservoirs are within reasonable distances from land, or where there are existing offshore O&G facilities and wells. The technical knowledge base of the petroleum industry can be leveraged for the development of CCS with a strong understanding of the pros and cons of offshore projects, operating experience with safe and economic CO2 capture, transportation, injection, and understanding of subsurface formations for future CO2 EOR/CCS applications. Introduction Oil and Gas Industry Experience The first patent for CO2 EOR was granted in 1952 (Whorton). The Texas Railroad Commission (TRRC report) proposed CCS rule states that " the first three projects (immiscible) were in Osage County, Oklahoma from 1958 to 1962.?? Another early CO2 EOR project was in Jones County, near Abilene, Texas in the Mead Strawn field in 1964 (Holm). The first large-scale, commercial CO2 EOR project (Langston) began operations in 1972 at the SACROC field in West Texas, which continues in operation today. Many more CO2 " flood?? EOR projects have started since then. By 2010, CO2 EOR projects had reached a global total of 127 (112 in USA) with 12 more planned for the USA, as reported in the EOR survey by the Oil and Gas Journal (O&GJ, 2010). Rising oil prices, low cost sources of high purity CO2, and access to miscible fields with large amounts of unrecovered oil have supported growth in CO2 based EOR in the U.S., which now accounts for 272 mbd (O&GJ, 2010) or over 8% of total Lower 48 crude production of 3.22 mmbd in the 2nd quarter 2010, as reported by the U.S. Energy Information Administration.

Focus on Carbon Capture and Storage (CCS) has grown over the past decade with recognition of CCS’s potential to make deep CO2 emission reductions and that fossil fuels will continue to be needed to supply much of the world's energy demands for decades to come. How CCS will compare to other options in the future depends critically on the cost of CCS (the focus of this paper) and resolution of barriers to CCS deployment, as well as costs and barriers for other emission reduction options. This paper provides a comparison of the cost of electricity of five power generation options – coal and gas Combined Cycle Gas Turbine (CCGT,) with and without CCS and nuclear – and shows regions of carbon price and fuel prices where each can be economically viable. Current cost estimates for coal CCS for Nth-of-a-kind power generation plant are in the 60-100 $/ton of CO2 avoided – higher than some of the earlier CCS estimates, and higher than the generally accepted range of expected carbon prices in the next two decades. The high cost of coal CCS suggests that:Gas based power generation is much more economical than coal CCS at carbon prices below 60-100 $/ton CO2.Even after carbon prices reach 60-100 $/ton CO2, gas CCS produces lower cost electricity than coal CCS as long as natural gas prices remain below 9 $/MBTU.Nuclear has a lower cost of electricity than coal CCS. Although Coal or Gas CCS is unlikely to be economical in power generation over the next two decades, subsidized demonstrations of CCS are likely to occur. In addition, components of CCS technologies will continue to be economically practiced in early use segments such as natural gas processing and Enhanced Oil Recovery (EOR) operations. In this paper, we share ExxonMobil’s experience at LaBarge in using CO2 from a natural gas facility for EOR use – the single largest CO2 capture site for sub-surface injection in the world today. In the natural gas processing industry, CO2 separation cost is a fraction of the cost of CO2 capture in power generation due to its higher gas pressure, and the CO2 separation is typically necessary to monetize the natural gas resource. In contrast, CCS for most refinery and industrial emissions is expected to be significantly more costly than power generation because the CO2 streams are typically smaller scale and more distributed than those from large power plants. Realistic estimates of cost for CCS, as well as for other greenhouse gas (GHG) mitigation options, are an important input for focusing research, development and demonstration (RD&D) addressing barriers to applications that show the greatest promise, and development of sound policy.

Carbon capture and storage (CCS) is believed to have a strong potential for reducing impacts from fossil fuel consumption on climate change. The inclusion of CCS into Clean Development Mechanism (CDM) in COP 16 is expected to mobilize global adoption of CCS, especially in developing countries where fossil fuel remains a cheaper alternative to meet fast growing energy demands. While fossil fuel demand may be supported with global deployment of CCS, concerns on energy security is likely to intensify competition between coal, oil, and gas as reliable sources of energy. For GCC countries, there is a strong need to understand the implication of large scale CCS deployment on demands for coal, natural gas, crude oil, and renewable energy. To address the complex issues at hand, we are working on the following research subjects; identifying socially optimal CCS regulation scheme taking into account CCS for CDM and the use of CO2 for Enhanced Oil Recovery (EOR), identifying optimal regulatory scope of CCS ...

Limits to Paris compatibility of CO2 capture and utilization

Given China’s economic dependence on coal for energy and industry, carbon capture, utilization and storage (CCUS) technology is a critical decarbonization strategy. Carbon dioxide (CO2) enhanced oil recovery (EOR) is critical to success of CCUS in China, providing the industrial know-how for long-term carbon storage. Carbon dioxide flooding in both China and the United States began in the 1960s. While the United States produces about 300,000 barrels of EOR oil per day, China’s EOR efforts still face significant hurdles. This paper presents a compilation and brief review of CO2-EOR data, some of it previously unpublished, from the three major Chinese oil companies (China National Petroleum Corporation, Sinopec, and Yanchang Petroleum Company) and one private company (Dunhua) that presently maintain pilot CO2-EOR floods. The authors have visited several of the projects discussed in the paper and some observations from these visits are included. China’s EOR projects generally produce from deep, tight, largely continental clastic reservoirs requiring hydraulic fracturing to create flow paths. There are no separation and recycle facilities—necessary to contain CO2 in the system-- and there are presently no supercritical pipelines for CO2 supply. Several CO2-EOR projects have established monitoring and storage pilot projects but the absence of recycle means determination of net storage is not possible. China’s projects could benefit from improved reservoir selection, new CO2 monitoring tools and operating strategies, expanded front-end investments in CO2 infrastructure such as pipelines and modern surface separation and recycling facilities that will serve to reutilize and store CO2.

Carbon Capture, Utilization, and Storage (CCUS) is a critical technology for reducing CO2 emissions in the oil and gas sector, contributing to global decarbonization efforts. This review explores the integration of CCUS technology in both offshore and onshore oil platforms, focusing on capturing CO2 emissions and either utilizing it for enhanced oil recovery (EOR) or storing it underground. The review begins with an overview of CCUS mechanisms, including CO2 capture techniques, utilization in industrial applications such as EOR, and storage in geological formations. The analysis delves into the unique challenges and opportunities associated with CCUS deployment in offshore platforms, including infrastructure requirements, marine environment considerations, and case studies of successful offshore projects like Norway’s Sleipner. Onshore oil platforms are also examined, with a focus on proximity to CO2 sources, infrastructure costs, and notable onshore CCUS initiatives. The review highlights the dual benefits of CO2-EOR, which boosts oil recovery while simultaneously sequestering CO2, extending the operational life of oil fields. However, challenges such as the technical barriers to CO2 retention, high costs, and regulatory uncertainties are discussed. Technological innovations, including advanced capture methods and improved storage monitoring, are identified as potential pathways to overcoming these obstacles. Future prospects for large-scale CCUS deployment are considered, emphasizing the need for public-private partnerships, policy support, and investment to scale up the technology and ensure its role in achieving net-zero emissions. This review underscores the importance of CCUS in reducing the environmental impact of oil and gas operations, while offering economic incentives through EOR and the long-term potential for sustainable energy transition.