Carbon Dioxide Capture And Storage Project Research Articles

Ranking Of Indonesia Sedimentary Basin And Storage Capacity Estimates For Co2 Geological Storage

The various possible strategies to combat global warming are explored within a wideranging of efforts. Practical solutions will need to stop or even reverse the build-up of CO2 in the environment by using existing technology that has not been integrated, carbon dioxide capture and storage (CCS) (Hansson, 2008). The main objectives of this study are to develop criteria for sedimentary basins ranking system in terms of their suitability for CO2 storage and estimate the storage capacity available. We adapt the method developed by Bachu (2003) to the Indonesia geological characteristics. Once the criteria has been developed and the basins ranked based on their suitability, oil and gas fields located within these basins were estimated their potential storage capacity using the methodology developed by Carbon Sequestration Leadership Forum (CSLF). From 60 identified sedimentary basins, Kutei, Tarakan and South Sumatera basins are respectively positioned in top three of the ranking system. Well known geological structure, adequate data, relatively stable geological structure and established infrastructures are the main factors make these basins have higher suitability. Estimation result showed from 48 fields that are considered depleted from their Np/Ult ratio (hydrocarbon cumulative production over ultimate recovery), Riau and South Sumatera region have large storage capacities which are around 229 and 144 MtCO2 respectively. The ranking of Indonesia sedimentary basins can then be used in making decisions for the large-scale implementation of CCS Project. The potential storage capacity might increase as data more available. The estimates resulted from this study is not a conclusive estimation where degree of geological and economic uncertainty associated with a capacity estimate is still high. However, from this estimation shows that Indonesia has huge potential of CO2 storage in depleted oil and gas reservoirs

Acorn: Developing full-chain industrial carbon capture and storage in a resource- and infrastructure-rich hydrocarbon province

Research to date has identified cost and lack of support from stakeholders as two key barriers to the development of a carbon dioxide capture and storage (CCS) industry that is capable of effectively mitigating climate change. This paper responds to these challenges through systematic evaluation of the research and development process for the Acorn CCS project, a project designed to develop a scalable, full-chain CCS project on the north-east coast of the UK. Through assessment of Acorn's publicly-available outputs, we identify strategies which may help to enhance the viability of early-stage CCS projects. Initial capital costs can be minimised by infrastructure re-use, particularly pipelines, and by re-use of data describing the subsurface acquired during oil and gas exploration activity. Also, development of the project in separate stages of activity (e.g. different phases of infrastructure re-use and investment into new infrastructure) enables cost reduction for future build-out phases. Additionally, engagement of regional-level policy makers may help to build stakeholder support by situating CCS within regional decarbonisation narratives. We argue that these insights may be translated to general objectives for any CCS project sharing similar characteristics such as legacy infrastructure, industrial clusters and an involved stakeholder-base that is engaged with the fossil fuel industry.

The influence of CO2 leaking on environmental monitoring in the process of CO2 geological sealing

Carbon dioxide capture and storage (CCS) is one of the most promising emission reduction measures. Based on the CCS project in Shen Hua Group Corporation, the eddy correlation monitoring system was used to monitor the CO2 flux in the sealed area. Combing with local wind direction, the flux change in the sealed area was analyzed. A simulation study on the CO2 leaking rule is carried out by ANSYS. CO2 distribution law in the sealed area in different leaking rates was predicted. The results show that the flux anomaly was caused by the CO2 leaking from surge tank in the sealed area. The interference on gas leaking from the surge tank should be considered in the monitoring process of the CCS project.

Perspectives of Geological CO2 Storage in South Korea to Cope with Climate Change

Rapid industrialization and urbanization in the 20th century have led to increasing volumes of carbon dioxide being released into the atmosphere[...]

Effect of Large Flow CO2 on Indexes of Water Quality and LD50 of Crucian Carp

CCS (Carbon dioxide capture and storage) is an effective way to reduce carbon dioxide levels of atmosphere in the near future. However, due to the geological problems in storage areas and the technical problems of CO2 injection, there is still a risk of CO2 leakage during the implementation of CCS projects. Once the stored CO2 leaks through water body, the water quality, aquatic ecosystem and fisheries in the leakage areas will be affected. Therefore, the research on impacts of CO2 on water quality and aquatic ecosystem is significant for the promotion of CCS project. The effects of different CO2 flow rates on indexes of water quality and crucian carp mortality were investigated by injecting CO2 into aquarium. In the impact experiment of CO2 to water quality, three indicators which included pH, DO (dissolved oxygen) and DCO2 (dissolved carbon dioxide) were chosen, and four types of experiments were designed in the research which included blank water, fish-farming water, water with injecting CO2 and fish-farming water with injecting CO2. The acute toxicity test included preliminary experiment and formal experiment. The 24-hour all-dead flow rate (LD100) and the 96-hour non-dead flow rate of CO2 (LD0) were determined by preliminary experiment. The equal logarithmic interval method was used to set the groups of CO2 flow rates based on the above flow rates. The survival number and mortality of experimental fish in each group were recorded and calculated at 24h, 48h, 72h and 96h. At last, the LD50 of CO2 flow rate at each node of time was calculated according to the improved Karber method. The main conclusions were obtained as follows: (1) The average background values of pH, DO and DCO2 in blank water were 7.69, 8.58mg/L and 10.05mg/L respectively. The average values of pH, DO and DCO2 in fish-farming water were 7.26, 7.31mg/L and 43.78mg/L respectively. Comparing the above conclusion, pH and DO in blank water were slightly higher than that in fish-farming water, while the DCO2 was lower obviously. (2) When CO2 was injected into the non-fish farming water, pH and DO decreased and DCO2 increased with time, and all indexes balanced quickly. The larger the CO2 flow rate, the shorter the equilibrium time. The equilibrium values of pH and DO decreased with CO2 flow rate, whereas the equilibrium concentration of DCO2 increased with CO2 flow rate. When CO2 was injected into the fish farming water, all indexes in water had the similar rule with the non-fish farming water. Comparing with the indexes of water quality in non-fish-farming water with injected CO2, pH and DCO2 in fish-farming water with injecting CO2 were higher, while the DO was lower. The reason may be the dissolution of CO2, fish's respiratory consumption, and neutralization of ammonium ions formed by manure decomposition. (3) According to preliminary experiment of acute toxicity, the 24-hour all-dead flow rate of CO2 (LD100) was 800 mL/min, and the 96-hour non-dead flow rate of CO2 (LD0) was 100 mL/min. The acute toxicity test showed that the mortality of crucian carp increased with time and CO2 flow rates. According to the semi-lethal experiment of the modified Karber method, the LD50 of CO2 to crucian carp at 24h, 48h, 72h and 96h was 1490±326 mL/m3﹒min, 799±181 mL/m3﹒min, 503±66 mL/m3﹒min, 427±0 mL/m3﹒min, respectively. (4) According to above results, the CO2 leakage of the CCS project can be evaluated by monitoring of surface water quality and crucian carp's mortality rate in the future.

Using Pressure Recovery at a Depleted Gas Field to Understand Saline Aquifer Connectivity

A key uncertainty facing Carbon dioxide Capture and Storage (CCS) in saline aquifers is long term injectivity, which is primarily a function of the connected aquifer pore-volume within which formation brine can be displaced as the CO2 is injected. Protracted injection testing to interrogate and prove the far-field connected pore-volume would increase the lead-in times for commissioning of storage sites and would significantly increase appraisal costs. Here we use natural gas production and subsequent reservoir recharge legacy data from the Esmond gas field in the UK sector of the southern North Sea to gain an understanding of the dynamic behaviour of the Bunter Sandstone, a major saline aquifer. Results suggest that Esmond has a connected pore volume of 1.83x1010 m3, suitable for injecting CO2 at a rate of up to 2 million tonnes per year for at least 55 years. 3D seismic data suggest that Esmond reservoir properties are likely to be replicated across the wider Bunter Sandstone aquifer, notably around the Endurance structure which was, until recently, proposed for a full-chain CCS project.

Density Measurements of Supercritical CO2 + Dagang Brine for CO2 Geological Storage

Carbon dioxide capture and storage (CCS) in saline aquifers has been considered as one possible means of reducing greenhouse gas emissions and mitigating climate change. The density difference of 0.1 kg·m·-3 is sufficient to drive a natural CO2-bearing solution to either sink or buoy, which is one of the main factors affecting the safety of CO2 storage. The density of CO2 aqueous solution is also necessary to estimate the storage capacity of the storage formation. Therefore, the density change due to the dissolution of CO2 is essential for simulation of CO2 sequestration process and CO2 migration in the formation.The density experiments were performed using a magnetic suspension balance (MSB) manufactured by Rubotherm Priizisionsmesstechnik GmbH. The measuring conditions (temperature, pressure and measuring medium) can be artificially controlled because the balance and the measuring cell were completely isolated. Taking full advantage of the high accuracy and stability of the magnetic suspension balance, this paper reported the experimental densities of CO2-brine solution from Dagang Oilfield reservoir. The densities of CO2 brine mixture were measured in CO2 geological storage conditions such as 313K-353K, 10-18MPa and CO2 mole fraction in solution up to 0.0123. The effects of different conditions on CO2 aqueous solution density were analyzed based on the experimental data. It was found that the density of CO2 aqueous solution increases linearly with the pressure and the slopes at different concentrations are almost the same at a certain temperature. We also found that the dissolution of CO2 in brine will increase the density of aqueous solution in our experimental conditions. And at a constant pressure, the density of CO2 aqueous solutions increases with increasing CO2 concentration almost linearly in the experimental range. It provides systematic experimental density data for Tianjin Dagang CCS project.

What's in store: Lessons from implementing CCS

Carbon dioxide capture and storage (CCS) has been identified as a key technology for mitigating carbon emissions. However, CCS is still very much at a developmental stage and the full-scale projects required to test the technology have proven difficult to implement, with lack of societal acceptance considered a key contributing factor to this delay. This paper reports on a study that explored practices for effective communication, engagement strategies and activities in the context of five detailed CCS project case studies. The cases studied included Barendrecht, The Netherlands; Carson, USA; FutureGen, USA; ZeroGen, Australia; and the CO2CRC Otway project, Australia. Comparative analysis of these cases identified a series of factors including: the extent to which key government and project team members are aligned; deployment of communications experts as part of the project team from the outset; consideration of the social context; the degree of flexibility in the project; and competition involving community self-selection. The research team designated these “critical success factors” that, when present, seemed to enhance the effectiveness of best practices in engagement and contribute to successful project deployment in some cases. The paper proposes that project developers need to consider ways to maximise these critical factors as part of their project planning and implementation process. It also discusses best practices in stakeholder communication and engagement activities applicable to CCS projects.

CO2 mitigation model of future power plants with integrated carbon capture and storage in Thailand

Thailand currently relies on natural gas, coal, and oil for electricity production. Natural gas and oil fields are the plentiful domestic energy resources in the Gulf of Thailand, but are projected to be available only in the next decade. Using domestic natural gas would reduce national energy security. Due to its low price, coal will dominate in electricity generation in Thailand. However, more utilization of coal results in increasing CO2 emissions. To comply with the low-carbon society policy of the Royal Thai Government, carbon dioxide capture and storage (CCS) for the future committed power plants in Thailand is introduced and analysed using the market allocation model, a least-cost energy planning tool. In this study, CO2 mitigation scenarios include integrated CCS to new gas- and coal-based power plants, nuclear power and renewable-based power plants and these were introduced as mitigation options. In energy-demand forecasting, share of coal-based plants is projected to increase from 0.72% in 2006 to 14.97% in 2030, while the share of gas-based plants decreases from 79.24 to 53.25% in the same period. This study also presents possible gas and oil fields for storing CO2 in the deep saline aquifer in the Gulf of Thailand. Results show the optimal CO2 incremental cost and revenue when applied with clean development mechanism and feed-in-tariff for renewable energy and the CCS project in Thailand.

이산화탄소 포집 및 지중저장(CCS) 기술의 청정개발체제(CDM)로의 수용 여부에 대한 정책적 고찰: 지중저장과 관련된 이슈 및 대응방안

기후변화 완화를 위한 온실가스 감축 수단으로서 이산화탄소를 포집하여 저장하는 이산화탄소 포집 및 저장(CCS) 기술의 중요성이 날로 부각되고 있다. CCS 기술은 발전소 등 대규모 배출원에서 배출되는 대량의 이산화탄소를 바로 감축 가능케 할뿐 아니라 경제 성장을 위한 탄소 에너지 산업 구조를 지속 가능하게 한다. 이러한 CCS 기술의 유용성으로 인해 현재 기후변화협약회의(UNFCCC)에서 청정개발체제(CDM)로 수용하는 방안을 논의 중이다. 그러나 CCS 사업을 CDM 체제로 수용함을 논의함에 있어서 몇몇 이슈들이 제기되고 있는데, 여기에는 ⅰ) 장기 영구성을 포함한 비영속성 ⅱ) 측정, 보고 및 검증(MRV), ⅲ) 환경 영향, ⅳ) 사업 범위, ⅴ) 국제법, ⅵ) 책임문제, ⅶ) 부당한 성과, ⅷ) 안전성 그리고 ⅸ) 보험 등이 포함된다. 본 논문에서는 이러한 이슈들을 정리 및 분석하고, 이를 통해 현재 우리나라가 계획하고 있는 CCS 실용화를 위해 선행되어야 할 정책적 고려 사항을 도출하고자 한다.

Life cycle assessment performed on a CCS model case in Japan and evaluation of improvement facilitated by heat integration

Abstract Carbon Dioxide Capture and Storage (CCS) is a technology for reducing the amount of CO 2 to be emitted into the air, by storing the CO 2 . However, a CCS project itself emits some CO 2 . Therefore, to estimate CCS’s net CO 2 reduction effect, it is effective to apply life cycle assessment (LCA) to CCS projects. In this paper, we assumed a number of CCS project models to be feasible in Japan, and estimated the amount of CO 2 emissions to store one ton of CO 2 by applying LCA to the CCS projects. As a result, depending on the model case, 50% or more of the CO 2 amount to be stored was emitted. The study also revealed that approximately 80% of the CO 2 emissions at CCS-applied facilities derived from the energy consumed to re-heat the liquid absorbent that absorbed CO 2 . The study also indicated that a substantial amount of CO 2 emissions can be reduced if heat integration is conducted between the production equipment and the CCS equipment for energy utilization, such as bleeding CO 2 from a power station and other production equipment.

A model of carbon capture and storage with demonstration of global warming potential and fossil fuel resource use efficiency

Abstract Increasing greenhouse gas concentration in the atmosphere influences global climate change even though the level of impact is still unclear. Carbon dioxide capture and storage (CCS) is increasingly seen as an important component of broadly based greenhouse gases reduction measures, such as the use of renewable energy sources or nuclear energy. Although the other greenhouse gases are more potent, the sheer volume of CO2 makes it dominant in term of its effect in the atmosphere. The International Energy Agency (IEA) uses 19% of emission reduction requirements as the target for CCS. Although a fossil fuel power plant is a large source of CO2 emissions, with CO2 capture these emissions can be reduced substantially. However, it must be recognized that CO2 capture significantly decreases power plant efficiency; therefore, extra resources (for example, coal in the case of a coal-fired power plant) are needed to compensate for the lost capacity. Extensive application of CO2 capture will require the construction of replacement power plants to compensate for the loss of electricity to the grid. CO−2 transport and storage also contribute to an increase in emissions and waste generation, as well as an increase in energy and other resource consumption..To understand the implications, CCS activities should be studied from a full life cycle perspective. The objectives of this study is to conduct life cycle assessment of combining two energy systems, coal-fired power plant and CO2 EOR, as a new tool to evaluate environmental LCA of CCS with CO2 EOR option. In addition, this is an attractive tool for decision making of any CCS project. Various equations are applied into the GaBi software (a LCA software) to model this tool. Life cycle assessment (LCA) is the primary approach used in this study to create the tool for CCS environmental evaluation. The Boundary Dam Power Station (BDPS) and the Weyburn-Midale CO2 Project in Saskatchewan, Canada, are studied and modified as the case scenarios to find the potential and encourage the appllications of CCS on both energy systems. Energy, using GJ as one of its unit, is considerably the product of this combining two energy resources as one system. The application of this tool effectively demonstrates the result of CCS system as life cycle impact assessment (LCIA) on carbon footprint and resource depletion. Other environmental impacts can, therefore, be analyzed by this tool as well. Three processes; coal mining, power plant including CO2 capture unit operation and crude oil usage, must be presented when the global warming potential (GWP) of CCS is performed. In addition, the result demonstrates the GWP reduction is directly related to fossil fuel resource use efficiency. This means the lower GWP of CCS, the lower efficiency of fossil fuel resource use as well.

Second Generation CO2 FEP Analysis: CASSIF - Carbon Storage Scenario Identification Framework

Carbon dioxide Capture and Storage (CCS) is a promising contribution to reduce further increase of atmospheric CO2 emissions from fossil fuels. The CCS concept anticipates that large amounts of CO2 are going to be stored in the subsurface for the long term. Since CCS is a rather new technology, uncertainties related with the future evolution of a CO2 storage system should be addressed in a systematic framework. Performance and risk assessment frameworks are being created for the evaluation of the safeness and effectiveness of a CCS project. The recommended first step of this framework is a qualitative analysis, which encompasses the scenario analysis. The main goal of this step is to identify CO2 release scenarios, which can be supported by using a database of Features, Events and Processes (FEP), i.e. the elements that describe the characteristics and behaviour of the geological system. A qualitative FEP database tool assists to describe the storage concept and the factors which might influence the future behaviour of the storage reservoir and its surroundings. Scenario analysis using a FEP database is a crucial part of the risk assessment of a CCS project and has been applied to define release scenarios for a number of storage sites. However, further improvement is needed to facilitate a faster and more coherent analysis. For this purpose, a novel scenario analysis framework has been created, called Carbon Storage Scenario Identification Framework (CASSIF) (Yavuz et al., 2008 [1]). It is based on the three major CO2 release scenarios (well, fault and seal) from where the relevant events and processes are identified and modelled. Expert opinion is a key value within this framework. A questionnaire to be filled in by experts has been designed for the initial screening and ranking of events and processes. Features (static entities) have been separated from the events and process (the dynamic characteristics) so the focus in the expert elicitation will be on the latter. The new interface facilitates the online use of the FEP database. Together with real-time scenario formation, these improvements will greatly enhance the speed, transparency and comprehe nsiveness in the creation of subsurface CO2 release scenarios.