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Addition of a CO 2 capture system to an existing power station has some impact on water consumption. CO 2 capture systems require additional water for cooling and process make-up. During the past decade, a number of relevant studies have been published that estimate the increase in water use when a capture system is added to Pulverized Coal (PC), Natural Gas Combined Cycle (NGCC) and Integrated Gasifier Combined Cycle (IGCC) power generation facilities. This paper provides a comprehensive analysis of these estimates available for post-, oxy- and pre-combustion CO 2 capture systems, making it possible to compare different technologies, and to better understand how adding a CO 2 capture system on a power plant impacts the volume of water withdrawn and consumed. The results of this study serve to dispel myths about the use of water in CCS systems. Specifically, they challenge the generic statement that CCS systems will double water consumption, which is often reported in papers and articles. Water use estimates cannot be generalized and are very dependent on the power plant type, the CO 2 capture technology and the cooling system used. The estimates indicate that for power plants served by wet-recirculating systems, the increase in actual water consumed varies approximately from 20 to 60 per cent, depending on the capture technology. For once through cooling systems the increase can be negligible, or even be negative when water recovery options are implemented. [ABSTRACT FROM AUTHOR]

Many companies that produce fossil fuels or fossil fuel-derived products show a strong belief in a large and continuing role for fossil fuels in the global economy up to 2050 and beyond. These companies are generally expected to be amongst the primary consumers of carbon capture and storage (CCS) technology. So far, however, fossil fuel companies have shown only moderate interest in CCS. Whilst a lot of potential operational barriers to CCS adoption have been identified in the literature, the value of CCS from a corporate strategy perspective has sometimes been assumed, but rarely explored. This paper asks the following question: What are the perceptions and positions of fossil fuel companies on CCS and how does this inform their decision-making on CCS investment and advocacy? This paper addresses this issue by presenting the results of in-depth interviews with high-level CCS experts from major multinational oil and gas companies and major coal mining firms. The results indicate that CCS would require a significant change within the business strategy of fossil fuel companies. This is contrary to the common argument that CCS is attractive because the technology is regarded as not being very disruptive to the incumbent energy system as it leaves most of the existing infrastructure, actor constellations and institutions intact. While fossil fuel companies engage in CCS development, it is often to familiarise themselves with technologies that might have future value if markets for these technologies take off. In several cases, CCS engagement has served the strategic need to weaken the link between fossil fuel extraction and climate change, build up shareholder trust, and improve public perception. However, there is little evidence that these companies engage in CCS to develop a strategic insurance against climate policy risks to their core businesses. [ABSTRACT FROM AUTHOR]

Numerous legal and regulatory frameworks in the U.S. and globally are acknowledging the opportunity for greenhouse gas (GHG) emissions reductions offered by combining the long-term storage of CO 2 in association with carbon dioxide enhanced oil recovery (CO 2 -EOR), to support carbon capture and storage (CCS) as a climate mitigation technology. These include the U.S. Environmental Protection Agency (USEPA), the International Organization for Standardization (ISO), the State of California, and the Intergovernmental Panel on Climate Change (IPCC), among many. In this paper, a brief overview is provided of the literature on GHG lifecycle analyses (LCA) applied to CO 2 storage in association with CO 2 -EOR. Then, various techniques for performing LCA related to CO 2 -EOR operations are summarized. Moreover, since most past LCA analyses of CO 2 -EOR projects were generally based on historical CO 2 -EOR operations, LCA based on assumptions from these operations are likely not to represent future emissions reduction opportunities where CO 2 storage is a co-objective with increased oil production. Thus, the paper examines different CO 2 -EOR development options that could greatly increase the amount of CO 2 injected, and ultimately stored, to recover incremental oil via the application of CO 2 -EOR, and speculates on how even greater storage efficiencies with CO 2 -EOR can be realized. Assuming historically-based values for CO 2 utilization, most life cycle analyses of CO 2 storage in association with CO 2 -EOR show that the emissions associated with producing, processing, transporting and/or utilizing the incremental oil produced are greater than the CO 2 injected and stored in association with CO 2 -EOR. However, current CO 2 -EOR operations are achieving much higher utilization values, and assuming the wide-scale application of “next generation” technologies applied to existing and potential new resource targets, even larger utilization values are realizable. Recent work by Advanced Resources, for example, shows that “next generation” CO 2 -EOR applied to the main pay zone (MPZ) of oil reservoirs uses, on average , about 0.45 metric tons per barrel of oil produced, while CO 2 -EOR applied to the residual oil zone (ROZ) underlying and in between existing oil fields uses, on average , about 0.50 metric tons per barrel of oil produced. Many projects are likely to achieve even higher values of CO 2 utilization for CO 2 -EOR. These utilization values are over double that assumed in most traditional LCA analyses applied to CO 2 -EOR operations. And even greater utilization values are realizable. For comparison, emissions associated with the production, transport, refining, and ultimate combustion of the incremental oil produced are estimated to be on the order of 0,42 to 0.43 metric tons per barrel. Given these values for CO 2 utilization with CO 2 -EOR, accounting for emissions associated with CO 2 -EOR operations, with activities downstream of CO 2 -EOR operations (i.e., crude oil transport and refining), and even accounting for the combustion of fuels created from the barrel of crude, the amount of CO 2 injected and stored in the reservoir during CO 2 -EOR can generally be greater than that associated with the emissions associated with the incremental oil produced. Going forward, it will be important that legal and regulatory frameworks for verifying and accounting for GHG emissions reductions acknowledge the importance of CO 2 storage with CO 2 -EOR in achieving GHG emissions goals. [ABSTRACT FROM AUTHOR]

The EC 2030 Framework acknowledges that CCS may have an important role in reducing direct emissions from industrial processes on the scale needed in the longer term. In this paper the potential of applying different CCUS concepts to different industrial applications in Finland has been evaluated from both the economic performance as well as the emission reduction potential point of view. The overall CO 2 emissions from industry as well as the heat and power sector in Finland were in 2013 about 52 Mt of which the estimated biogenic emissions comprise about 24 Mt. The results from this work show that with a CO 2 emission allowance price of 50 €/t, CCS would be economically feasible for 8 Mt CO 2 /a, covering transport and storage costs. Most of the cost-effective CCS applications in Finland would be in the biomass power & heat sector and in the pulp and paper industry. However, this requires that “negative” emissions from bio-CCS are acknowledged and included in the EU emission trading system. CCS does not provide a simple solution to reduce CO 2 emissions in Finland as there are no suitable formations for CO 2 storage, which means that CO 2 export would be required. However, a range of CO 2 utilisation options could be attractive. [ABSTRACT FROM AUTHOR]

In large and complex processes use of simulators will take place more and more in the future to avoid and learn about transients and unexpected situations. There are plenty of dynamic simulation tools in the markets but most of them have been developed and used for quite specific and limited application areas. At the moment there are just few simulation tools which are capable to handle dynamically in the same simulation case challenging process areas like combustion, distillation, chemistry and control of very large process areas. For this reason, in this study, there was a need to carry out co–simulation where two dynamic simulation tools Apros and Aspen Plus Dynamics were combined together by using Matlab Simulink as an interface. The co–simulation approach was a way to construct large dynamic process simulation environment, where typical operational transients and failure situations of an oxy fired power plant were possible to test and analyze. Under EU 7th Framework Programme (FP7) the FLEXI BURN CFB project an oxy firing concept based on circulated fluidized bed (CFB) combustion and supercritical once-through (OTU) water steam cycle was developed and successfully demonstrated [1] . This project also generated a dynamic simulation model of the 1st generation oxy firing concept, as we call it. In the EU 7th Framework Program's project O2GEN (Optimization of Oxygen-based CFBC Technology with CO 2 capture), the 2 nd generation concept of CFB based oxy firing was developed. The target of the project was, at first, to increase O 2 content in recirculated flue gas to see what kind of effect it has to the heat exchange and corrosion in the boiler. Secondly, the target was to carry out exergy analysis to increase the whole concept efficiency by decreasing energy consumption in the boiler, Air Separation Unit (ASU) and CO 2 -purification unit (CPU). Based on these steady state analysis means the refined concept was then modelled for dynamic simulations which were carried out by using Apros and Aspen Plus Dynamics dynamic modelling tools in a co–simulation mode. This paper deals with dynamic simulation of the 2 nd generation 600 MW oxy fired CFB once trough boiler. In this paper we will present the dynamic model which includes oxy fired CFB boiler, turbine island, ASU and CPU with all needed equipment like heat exchangers, pipes, pumps, air and fuel feeding systems, distillation columns and sequestration vessels. Automation like measurements, controllers and actuators are included in the model. The simulation case selected for this paper presents an analysis what happens when one of the oxidant fans trips on boiler full load operation and how to handle this kind of failure by decreasing the boiler load to sufficient level of regarding the available oxidant feeding capacity. There were several items which were taken into account in the boiler, turbine island, ASU and CPU side when this kind of failure takes impact. The main findings in the failure analysis will be presented. Finally, discussion and future aspects of the simulation approach described will be given. [ABSTRACT FROM AUTHOR]

The South West Hub project, through three generations of modelling based on new 2D and 3D seismic data and core/log information from four new wells is demonstrating that carbon dioxide storage is possible in an environment where there is no regional shale layer acting as a traditional seal. This paper summarises the work that has been undertaken in a collaborative manner into “unconventional geology” exploring migration assisted trapping in an on-shore saline aquifer by Government, private sector contractors and researchers in the south west of Western Australia. Carbon Capture and Storage (CCS), which involves capturing carbon dioxide that would otherwise be emitted to the atmosphere and injecting it to be stored in deep geological formations, is a potential stepping stone to maintaining energy security while reducing the carbon footprint of Australia's energy sources. CCS is the only technology available to make deep cuts in greenhouse gas emissions while still using the fossil fuels that power much of today's energy infrastructure. At a State level, the Western Australian Greenhouse Strategy incorporates CCS and is helping to address the need for a long-term commitment to climate change and cleaner energy. The Western Australia Department of Mines and Petroleum (DMP) started investigating the Lesueur site, near large CO 2 emission sources (the industrial centres of Kwinana and Collie in the South West of Western Australia) in 2007 and developed the South West Hub (SW Hub) project concept in 2010 with the support of local industrial partners. The project was designated an “Australian Flagship” project in 2011 and has received substantial funding and support from the Federal Government, through the Department of Industry Innovation and Science) the Western Australia State Government and industry. The SW Hub Project is progressing data acquisition and analysis aimed at establishing confidence in storage associated with migration assisted trapping (MAT) in unconfined saline aquifers. The storage complex has no regional shale layer and consists of the Lower Lesueur (Wonnerup Member) as the injection reservoir, the Upper Lesueur (Yalgorup Member) with its numerous paleosol baffles as the lower confining layer and the basal shale part of the Eneabba Formation as the upper confining layer. The injection reservoir is a heterogeneous sandstone that is over 1500 m thick with varying permeability layers that should support residual and solubility trapping. From the very onset, the SW Hub Project has followed a rigorous stage gated decision making program. The project has been divided into phases and each phase involves targeted data acquisition plans to address technical gaps or uncertainties. These uncertainties have been documented in an Uncertainty Management Plan (UMP) and drive all technical work. “Decision Gates” ensure that, only on increased confidence of success would the project move to the next phase. The project processes are consistent with the DNV CO2QUALSTORE steps and the workflows defined in the EU Directive 2009/31/EC guidance document. Under the first phase of the new data acquisition program (2011-12), new geological data was gathered through 100 km of targeted 2D seismic lines and one deep exploration well drilled to 2,945 metres. Multiple modelling scenarios with differing assumptions on the geological properties supported the storage concept and identified no “show stoppers”. Notwithstanding, uncertainty planning required additional data to address the gaps identified. Under the next phase of the development program (2013-15), 3D seismic was acquired over 115 km 2 and additional wells planned. The area of interest is dominated by farming activity and not all landowners provided consent to acquire the seismic data. As such, while high fold data has been acquired over the deeper Wonnerup Member reservoir sections, the shallower Yalgorup Member was not as well illuminated. The drilling strategy was adapted to maximise geological coverage particularly across the shallower reservoirs. Three wells were drilled using a combination of mineral and water well drilling rigs with a deeper well to be considered following model updates. Significant technical work has also been done to support this development through a range of research projects launched under the auspices of the Australian National Low Emissions Coal research and development program (ANLEC R&D). These projects are focused on reservoir characterisation and either consider more fundamental physics based questions or delve significantly deeper into specific geology and geophysics domains using laboratory and modelling efforts. Clear decision criteria to support additional investment in a drilling and testing program have been defined and will be addressed by modelling. The paper will explain the project challenges and the decision making rationale, highlighting the importance of good processes, long term planning, and extensive stakeholder management supported by a robust technical program. Results to date support MAT and validation of the SW Hub storage concept will substantially increase the number of geologic sites that can be considered for safe storage around the world. There is significant international interest in the project field and research activities. [ABSTRACT FROM AUTHOR]

The European Carbon Capture and Storage (CCS) Project Network (the “Network”) is currently composed of projects located in the Netherlands, Norway, Spain, and the UK. The goal of the Network is to accelerate deployment of CCS by sharing project development experiences about technology integration, regulatory environment and financial structures. This paper aims to provide a review of some CCS experiences gained from developing the Network projects. Besides technology and project development, sharing knowledge and lessons learned on project-level basis, also gives valuable insights on how to create policies that would assist more effective deployment of technology and can enable development and implementation of regulatory frameworks. Hence, knowledge acquired in CCS aspects during the early development of this technology in Europe will be presented in this paper. [ABSTRACT FROM AUTHOR]

A technology roadmap is the document that is generated by the technology road-mapping process. It usually identifies the critical system requirements, the product and process performance targets, and the technology alternatives and milestones for meeting those targets. In effect, a technology roadmap identifies alternate technology “roads” for meeting certain performance objectives. CCUS has great potential to reduce CO 2 emissions substantially from the whole lifecycle of traditional energy-intensive industry at a large-scale. In this paper, we do not want to address how to generally make a CO 2 technology roadmap. We are concerning about the gaps and suggestions which should be closed in the coming revision of China CO 2 technology roadmap 2011. The paper presents a summary of latest situations of international and national CCUS technical roadmaps. Then, the challenges existed in the past and also emerged currently in China are proposed. Finally, some comments and suggestions for the coming version of China's CCUS technology roadmap are displayed to guide ongoing development of CCUS in China based on the development situation and challenges of China CCUS RD&D in the past and at the present stage. [ABSTRACT FROM AUTHOR]

In January 2010, an integrated CO 2 Capture and Storage (CCS) project, including CO 2 capture, transportation and geological storage started in the Lacq-Rousse area, Southwest of France. Until March 2013, 51 thousands metric tons of CO 2 were injected into a fractured dolomitic depleted gas reservoir at around 4500-m depth. Key objectives of the project were to develop, test, and validate the methodology and the technology required for managing safely such storage operations, and in particular to define an “optimal” monitoring program, economically and technically viable. A monitoring plan was designed, including the deployment of a hybrid multi-scale passive seismic monitoring network to address 3 monitoring objectives: watch seal integrity, distinguish natural seismicity from induced seismicity, and assess injection-induced seismicity. A near-surface network (Master Network), and a downhole array deployed in the injection well (Research Network), were installed between 2009 and 2011. In addition, detection of regional seismicity was also available through a seismometer. Data have been collected for 9 months prior to injection, during injection, and also after injection, as part of the post-injection monitoring program planned for 3 years. Starting from March 2011, as per end July 2014, the hybrid system allowed detecting about 2500 events. Over two third of those events were not energetic enough to be located. Over 600 events, with estimated magnitudes above -2.3 and not exceeding -0.5 were located in the reservoir. The monitoring therefore helped in concluding that the CO 2 injection did not generate an adverse impact on reservoir integrity. Actual network performances have been in line with expectations. The effective Master Network location sensitivity is about magnitude -0.6 (completeness magnitude) in the volume of interest, confirming its ability to serve for an efficient seismic hazard monitoring. In this paper we show how the proper design of a passive seismic network consistent with the monitoring plan can benefit the different phases of a CCS project, and how passive seismic monitoring during the full duration of the injection can bring reliable evidence for reservoir integrity. The paper concludes that passive seismic monitoring with a limited number of near-surface sensors constitutes an effective alarm network. In addition passive seismic monitoring can provide a permanent seismic risk evaluation tool by continuously comparing seismic activity with the energy input into the reservoir. This second type of application is certainly not necessary for most oil and gas development, but it may constitute a precise element of monitoring if seismic hazards need to be closely monitored. [ABSTRACT FROM AUTHOR]

Carbon Capture and Storage (CCS) technology is one of the most promising technological solutions to realize low-carbon utilization of fossil fuels in a large scale. Under the leadership of the Ministry of Science and Technology (MOST), China and Italy initiated the “Sino-Italy Cooperation on Application of CCS to Coal Fired Power Plants” (SICCS) project which not only promoted CCS technology exchanges and scientific research collaboration between both countries, but also conducted a pre- feasibility study on a full chain demonstration project, including capture of CO 2 from coal fired power plant, CO 2 transport and storage. This paper will introduce the overall R&D collaboration progress on this project. It first reports activities designed to raise CCS capacity in China and to facilitate the knowledge sharing between Chinese and Italian academe, key outcomes of the SICCS project including the first and second Sino-Italian Scientific Meetings on technology exchange, information sharing, and preliminary feasibility study for CCS demonstration project in China. Then, this paper investigates the preliminary feasibility study of a 1.0 Mt/y carbon dioxide (CO 2 ) capture unit for an existing coal fired power station in China carried out by experts from both China and Italy. The study results obtained with reference to Chinese 600 MWe thermoelectric power plant were compared with those of Italian CCS demonstration project. Finally, this paper concludes main results of the collaboration and preliminary study, raises a new cross-boarder science and technology collaboration mechanism based on industrialization of scientific research cooperation and technology exchange by co-conducting demonstration projects. It also extracts main features of the processes and technologies that may be applied to the demonstrative application of CCS to the 600 MWe unit of Chinese coal power plant. [ABSTRACT FROM AUTHOR]

The IMPACTS project has a stated broad objective to develop the knowledge base of CO 2 quality required for establishing norms and regulations to ensure safe and reliable design, construction and operation of CO 2 pipelines and injection equipment, and safe long-term geological storage of CO 2 . More specifically for this paper, the project sets out to reveal the impacts of relevant impurities in the CO 2 stream on the design, operation and costs of the capture, transport and storage infrastructure and to provide recommendations for optimized CO 2 quality through techno-economic assessments (amongst other considerations). This paper gives an overview of the work being carried out to investigate the impact of CO 2 quality in various areas including corrosion, water content in the CO 2 stream and the injection and storage processes. The paper reports on the derived impacts of the above mentioned aspects of CO 2 quality. These impacts are combined with estimates of the cost of measures to mitigate or prevent these impacts from affecting the operation of the CCS system, or of adapting of CCS system design. Thus, the impacts can be set out as a set of cost functions relating to Capex and Opex and including the effects of overall availability and process efficiency changes. A specifically designed CCS chain model is used to assess the impacts on a number of reference CCS chains, carrying out comparative economic trade-offs to both understand the full- chain whole-life economics of certain CO 2 impurities at different levels and then to potentially optimize a purity specification for various sets of circumstances. [ABSTRACT FROM AUTHOR]

In 2012, China stated to the United Nations Framework Convention on Climate Change (UNFCCC) that it is very vulnerable to the effects of climate change. While climate change is an environmental issue for China, more importantly it is a development issue. China intends to advance its efforts to address climate change through sustainable development. There is growing recognition and acceptance by the Chinese Central Government, that Carbon dioxide Capture Utilization and geological Storage (CCUS) will be part of that sustainable development, and that CCUS will play a prominent role in China's climate change abatement strategies, particularly in the medium to long term. China is making significant progress in its rollout of integrated CCUS projects. China has enacted a new environmental law which will come into effect on 1st January 2015. For the first time in China the environment will be as important as socio-economic development. Despite this progress, there are currently no national environmental regulations specifically for CCUS projects in China. This paper examines China's plans to develop and implement environmental requirements for CCUS projects, the policy objectives and drivers. The paper also describes the CO 2 monitoring program at China's first end to end CCS project near Ordos; monitoring at China's first CO 2 EOR development at the Jilin Oil Field; and a program to monitor CO 2 in shallow groundwater in western China. [ABSTRACT FROM AUTHOR]

The Rotterdam Opslag en Afvang Demonstratieproject (Rotterdam Storage and Capture Demonstration project), or ROAD, aims to build and operate a 250 MWe equivalent CCS chain using post-combustion capture technology and off-shore storage in a depleted gas field under the North Sea. The capture plant would be retrofitted to a new 1 070 MWe coal-fired unit (Maasvakte Power Plant 3) in Rotterdam, Netherlands. It was originally intended to reach a final investment decision at the end of 2010, but the project has faced a series delay associated with permitting, complex commercial negotiations and, most seriously, funding. At the moment (September 2014), the European Commission and the Government of the Netherlands are engaged in a renewed push to solve the funding problems and allow construction to finally start. The project has financial support from the European Energy Programme for Recovery (EEPR) and the Government of the Netherlands and is now the only one of the six projects originally supported that still has any realistic prospect of being realized in the short term. This paper presents an update of the overall project development as at the time of GHGT-12 and the accomplished milestones and issues met in the permitting process. In addition, it will focus on the technical and economic aspects of integrating the capture plant with the power plant. Furthermore, it will provide an outlook on future CCS/CCU developments in Rotterdam, describing the steps under development to create a full CO 2 hub in the port including options for ship transport and bio-CCS. The paper concludes with the management of the project delays and the implications for the project economics. [ABSTRACT FROM AUTHOR]

The Midwest Regional Carbon Sequestration Partnership (MRCSP) is implementing a commercial-scale carbon capture and storage (CCS) project in multiple Silurian carbonate pinnacle reefs in northern Michigan that are in various phases of enhanced oil recovery. This paper presents analyses of five pressure fall-off tests performed sequentially during the injection of 166,000 tonnes of CO 2 into a Type-1 (depleted) reef which has undergone primary and secondary production. Bottom-hole pressures were monitored in the injection well and in two observation wells to record progressively increasing reservoir pressure during the injection period, which also included five fall-off tests. Pressure data were analyzed using combined history-matching and pressure derivative matching techniques implemented with a commercial well-test interpretation program, FAST WellTest™. The paper illustrates the challenges of consistently interpreting CO 2 injection fall-off tests under multi-phase flow with varying pressure conditions using a single-phase analytical model. This work is relevant to CO 2 sequestration in depleted oil reservoirs because regular fall-off testing is required under the U.S. Environmental Protection Agency's Underground Injection Control (UIC) Program for CO 2 geologic sequestration (75 FR 77230). [ABSTRACT FROM AUTHOR]

Abstract The goal of the multinational ACT project ELEGANCY is to accelerate the decarbonisation of the European energy system by exploiting synergies between carbon capture and storage (CCS) and hydrogen (H 2). The introduction of CCS is delayed due to lack of business models, the widespread use of H 2 is hindered by the cost and availability of large quantities of clean hydrogen. The five participating countries Norway, England, Netherlands, Switzerland and Germany want to investigate and evaluate the combination of a hydrogen infrastructure with CCS in case studies and develop a planning tool. The Ruhr-University Bochum is working interdisciplinarily with five institutes within the framework of the Research Department Closed Carbon Cycle Economy (RD-CCCE). Thus, in addition to the technical part, social, macroeconomic and legal aspects are considered in the German case study. This interdisciplinary approach is presented in this paper, describing the practices of the different disciplines. [ABSTRACT FROM AUTHOR]

Abstract Stabilization and reduction of the atmospheric carbon dioxide (CO 2) concentration will be one of the prime challenges for the energy sector in the upcoming decades. Carbon capture and storage (CCS) is widely seen as a possibility to continue fossil power generation while contributing to CO 2 abatement. In future energy systems with high shares of fluctuating renewable energy generation, nuclear power will become increasingly important for power generation. The development of natural gas power is considered as one of effective ways to reduce emissions and socio-economic costs as well. As a measure to establish a climate-friendly energy system, a power system research on coordinated development of nuclear and natural gas power would be considered. Therefore, future electrical power scenarios aimed at environmental and economic effects for China would considered a full mix of energy options. Based on the LEAP tool, this paper establishes a bottom-up model (LEAP-China-Power) to simulate different electric power planning policy scenarios that could be enacted from 2012 to 2050. In addition to a baseline scenario, we design CCS scenario and nuclear and Natural Gas Combined Cycle(N&N) scenario. The results indicate that N&N scenario is superior to CCS scenario. And China's future power planning recommendations are proposed. [ABSTRACT FROM AUTHOR]

The history of the CarbFix project spans 12 years. Throughout all this time, CarbFix has not faced problems with public acceptance in relation to carbon capture and storage (CCS) activities. This is noteworthy, as the project’s operations are located at Hellisheiði Geothermal Power Plant, which has been contested and scrutinized. It could even be argued that CarbFix has played an important part in increasing the Hellisheiði Plant’s acceptance. This paper describes the framework of stakeholder engagement and transparency in relation to industrial scale operations within CarbFix and the impact it has had public acceptance. [ABSTRACT FROM AUTHOR]

The effective technology for capturing CO 2 at the low concentration is chemical absorption, due to the high reactivity between CO 2 and aqueous amine solutions. To capture CO 2 , the process involves complex reactive separations. The accurate calculation of hydrodynamic properties, and mass and energy transfer are of importance for the design of the absorber and desorber columns. This paper performs the rate-based simulations of CO 2 absorption by Monoethanolamine in Aspen Plus. In the calculation of the mass transfer coefficients, different mass transfer models were implemented. In comparison with the desorber, the impacts of mass transfer models were more significant in the simulation of the absorber. For both columns, the impacts of the mass transfer models on the concentration profiles were more significant than those on the temperature profiles. For the absorber, the maximum deviations occur at the bottom of the column for both the concentration and the temperature profiles. Different from the absorber, for the desorber, the maximum deviations occur close to the top of the column. [ABSTRACT FROM AUTHOR]

The Sulcis Basin is an area situated in SW Sardinia (Italy) and is a potential site for the development of CCS in Italy. This paper illustrates the preliminary results of geological characterization of fractured carbonate reservoir (Miliolitico Fm.) and the sealing sequence, composed by clay, marl and volcanic rocks, with a total thickness of more than 900 m. To characterize the reservoir-caprock system an extensive structural-geological survey at the outcrop was conducted. It was also performed a study of the geochemical monitoring, to define the baseline conditions, measuring CO 2 concentrations and flux in the study site. [ABSTRACT FROM AUTHOR]

The CCS operations have not been progressed so much worldwide yet. As one of the reasons, it is considered that the operators are required expertise at the various stages in the field of CO 2 storage. One of the most difficult judgments for the operator is to determine CO 2 injection layer in a storage complex. This paper provides an idea of a simple method to help operator's judgment without special expertise. We tried to apply this method for the Nagaoka's data. The result suggests that it is possible to determine the injection layer from the conventional well logging without special equipment. [ABSTRACT FROM AUTHOR]

In recent years, investment into carbon capture and storage (CCS) technologies has been seemingly sidelined to encourage larger renewable energy generation investment. High initial CCS costs have to compete with decreasing renewable costs and in some scenarios the role of CCS is completely overtaken by renewable energy. However, not recognising the value of a wider variety of low-carbon options in an energy system and committing to a single low-carbon technology can lead to a reduction in flexibility and further down the line even a lock out from successfully adapting the system to new advancements in smart technologies. On the path to a greener British energy system, gas power plants are considered as the transitional technology given the intermittent nature of most renewable generation. CCS can play a crucial role in mitigating the polluting effects of conventional generation. This paper employs real options analysis (ROA) to explore various cost and flexibility states, accounting for various penetrations of CCS and renewables working in cohesion. [ABSTRACT FROM AUTHOR]

This paper summarises results from empirical research with the broad aim of exploring societal responses to CO 2 storage, framed around the concept of social license to operate (SLO). The essential characteristic of SLO is based on a partnership between communities, operators and government and is thus dependent on a variety of factors that contribute to building trust between the stakeholders. Drawing on data from media analysis, stakeholder interviews and focus groups deployed in two locations in the UK, we explore social factors that could influence an emerging SLO for CO 2 storage in the UK, drawing lessons from an analogous technology. [ABSTRACT FROM AUTHOR]

In this paper, a holistic approach taking into account process economics is employed in order to assess the true potential of first generation oxy-fired power plants. The proposed methodology is carried out in two-steps. The first step consists in the minimization of the energy penalty: an exergy analysis is performed on a conventional base-case oxy-fired power plant in order to identify the possible improvement paths, including structural modifications and thermal integrations. At the end of this step, the process layout leading to a minimized energy penalty is obtained. However, as the introduction of a process modification impacts the plant's CAPEX, each modification highlighted in the previous step is characterized by a techno-economic criterion in order to determine its profitability in a second step. The marginal cost of electricity production, defined as the ratio between additional CAPEX and the net production increase is used for the process modification assessment. This procedure has been applied on state-of-the-art processes in order to estimate the potential of first generation oxy-combustion power plant. The optimization solely based on an energetic criterion leads to a plant layout with an energy penalty of 6.0%-pts, which represents a 38% reduction (the energy penalty of the base case plant is 9.4%-pts). However, the consideration of economic aspects has highlighted that some of the considered process modifications were not justified on an economic stand point. The optimal oxy-fired power plant, from a techno-economic point of view, exhibits an energy penalty of 6.9%-pts and allows a 20% reduction of the CO 2 avoidance cost compared to the base-case oxy-fired plant. [ABSTRACT FROM AUTHOR]

This paper investigates post-combustion capture in coal-fired power plants equipped with gas separation membranes. Simulations are conducted with the process engineering software, Aspen Plus®, with its Exchanger Design and Rating (EDR) tool utilized for heat exchanger design. The reference power plant chosen for the investigation is the Reference Power Plant North Rhine-Westphalia (RPP-NRW) in Germany. The Polyactive ® membrane developed by the project partner, Helmholtz Zentrum Geesthacht, was used in the simulation. Because the membrane has different properties at different working temperatures in order to reach a higher degree of selectivity and less energy consumption, the flue gas should be cooled to 25 °C. This results in an efficient cooling system for the capture process, which merits further development. A rigorous heat exchanger design leads to a significant increase in the pressure drops at each heat exchanger and hence the pressure ratio required by the compression machines. The energy penalty of the membrane CCS system for 57% and 76% degrees of CO 2 separation was increased from 4.7%-pts to 5.3%-pts and 7%-pts to 8.3%-pts, respectively, after implementing the rigorous heat exchanger design. [ABSTRACT FROM AUTHOR]

This paper present the techno-economic assessment of an MEA-based CO 2 capture from a cement plant and the importance of the steam supply on the costs. The evaluations present the energy performances of the CO 2 capture process based on a cement plant with a clinker capacity of 3,000 t/d. The cost evaluation lead to a cost of cement of 45 €/t cement without capture, while the cost of cement with CO 2 capture is estimated to 81 €/t cement , resulting in a CO 2 avoided cost of 83 €/t CO2,avoided . As the steam consumption accounts for close to half of the CO 2 avoided cost, the impact of six alternative steam supply scenarios are considered. The evaluations show that the CO 2 avoided cost can decrease by up to 35% depending on the steam supply and electricity price. However the possibility of these steam supply alternatives are specific to the considered cement plant, emphasizing therefore that CO 2 avoided cost from cement shall rather be given as a range depending on the steam supply than as a unique value as often illustrated in the literature. [ABSTRACT FROM AUTHOR]

The UK Carbon Capture and Storage Research Centre co-ordinates a programme of research covering all aspects of CCS in support of basic science and UK government efforts on energy and climate change. This paper will present progress and ‘lessons learned’ from the Centre's activities, with a particular focus on the development and use of pilot scale facilities and encouraging industrial and other stakeholder engagement in research. It will also highlight key features of an extensive programme of international engagement activities undertaken by the Centre, identifying added value for both the UK CCS community and global development of CCS. [ABSTRACT FROM AUTHOR]

Assessment of well integrity has become more important for CCS and CO 2 -EOR as it has become apparent that wells represent the most likely migration pathway for CO 2 to leave a CCS storage unit or a CO 2 -EOR reservoir. Although wells represent a migration pathway they are also the best vehicle for employing technology monitoring CO 2 injection and storage. This contradiction of being a potential migration path and key monitoring technology leads to a need to understand how monitoring wells may be similar or different in comparison to other types of wells with respect to migration risk. The maturation and completion US Department of Energy sponsored research projects presents an opportunity to assess the integrity of monitoring wells that have been exposed to injected CO 2 . This paper discusses an integrity assessment of two monitoring wells in an operating CO 2 -EOR flood in Mississippi, USA. It provides an early assessment of how monitoring equipment affects well integrity and isolation capacity. Each of the monitoring wells in this study were similarly constructed using both fiberglass and conventional steel casing. Each of the wells was instrumented with multiple monitoring technologies including, electrodes, pressure gauges, and temperature sensors on the outside of the casing. Control lines and cables were run from the surface on the outside of the long-string casing in each well to communicate with the monitoring equipment. A comprehensive logging, testing, and sampling program was developed to assess integrity in both wells. Ultrasonic well mapping was used to create radial maps of the location of cement, liquid, and gas behind the casing. Cement bond logging provided information on the casing-to-cement and cement-to-formation bonds for the long-string section. The logs showed that the monitoring equipment attached to the long-string casing is visible as continuous low acoustic impedance features and may represent a leakage risk. Cased-hole sidewall cores were collected and provided some validation of the log results and provide local information on the isolation capacity of the wells. The combination of information from the log data sets and cores was used to assess isolation capacity. The results of the study show that careful design and assessment of the materials used in monitoring well construction, the types of monitoring technology, and the location of monitoring technology within a well needs to be conducted with limiting migration potential and maximizing well integrity as objectives. [ABSTRACT FROM AUTHOR]

This paper describes preliminary results of analysis using the Global Change Assessment Model (GCAM) to evaluate the potential role of CCS in achieving emissions reduction targets. Scenarios are modelled using the Paris-Increased Ambition (PIA) case developed by Fawcett et al. (2015), and a more aggressive Paris Two-Degree Ambition (P2A) case. Both cases are based upon nationally determined contributions (NDCs) agreed to at the UNFCCC Conference of Parties (COP-21) in December 2015, coupled with additional mitigation effort beyond the 2030 Paris timeframe, through the end of the century. Analysis of CCS deployment and abatement costs under both policy scenarios suggests that, as modelled, having CCS in the technological portfolio could reduce the global cost of addressing emissions reduction targets specified under the policy scenario by trillions of dollars. Through the end of the century, total global abatement costs over the century associated with the PIA case – with five percent annual reduction in emission intensity and reaching 2.2 degrees by 2100 – are reduced by $15 trillion USD in the scenario where CCS is available to deploy by 2025 and remains available through 2100, nearly halving the cost of climate change abatement. Under the more ambitious P2A case, with 8 percent annual reduction in emission intensity and reaching 1.9 degrees by 2100, the availability of CCS reduces global abatement costs by $22 trillion USD through the end of the century, again nearly halving the costs of addressing the policy, relative to achieving the same target using an energy portfolio that does not include CCS. PIA and P2A scenarios with CCS result in 1,250 and 1,580 GtCO 2 of global geologic storage through the end of the century, respectively. [ABSTRACT FROM AUTHOR]

The European Carbon Capture and Storage (CCS) Demonstration Project Network (the “Network”) is currently composed of projects located in the Netherlands, Norway, Spain, and the UK. The goal of the Network is to accelerate deployment of CCS by sharing project development experiences about technology implementation, including transport and storage of CO 2 , as well as regulatory environment and financial structures. This paper aims to provide an overview of some CCS insights gained from developing the Network projects. Besides technology and project development, sharing knowledge and lessons learned on project-level basis, have also given valuable insights on how policies can enable development and implementation of appropriate regulatory frameworks, and funding schemes towards effective deployment of CCS technology in power generation sector. [ABSTRACT FROM AUTHOR]

This paper investigates the technical feasibility of monitoring the Goldeneye storage site for containment with time-lapse Distributed Acoustic Sensing (DAS) VSP and DAS microseismic. Specifically, the study examines if the expected seismic signals are measurable with DAS, i.e. whether it would be possible to detect unintended migration of CO 2 in a timely manner with sufficient resolution and spatial coverage. In the case of Goldeneye, the multiplicity of wells and diversity of their trajectories provide a favorable geometry that compensates for DAS broadside sensitivity limitations. A ray trace modelling exercise demonstrates that a multi-well DAS VSP survey with minimized source effort can provide a high fold image of the main storage site in an area of approximately 2 km 2 around the platform and injectors. The feasibility of monitoring induced seismicity with DAS is evaluated in terms of the spatial distribution of minimum detectable moment magnitudes and event location errors. Provided the noise floor of DAS interrogation units will be reduced and given the Goldeneye well geometry, DAS microseismic may be a possible containment monitoring technology subject to field trial, noise characterization and further processing developments. The economics for DAS seismic solutions are advantageous given that a fiber optic cable can generally be cost-effectively installed in multiple wells and its use can be combined with other in-well monitoring applications, like Distributed Temperature Sensing (DTS). For the Goldeneye storage site, DAS VSP has been identified as a potential containment monitoring alternative to a much more costly surface seismic survey in the vicinity of the injector wells. [ABSTRACT FROM AUTHOR]

The calcium carbonate looping (CaL) process is a promising post-combustion technology for CO 2 capture from fossil-fired power plants and carbon intense industries like steel and cement manufacturing. A CaL system consists basically of two interconnected circulating fluidized bed (CFB) reactors using natural limestone as a sorbent. Inside the carbonator, CO 2 contained in the flue gas is absorbed by the exothermic carbonation reaction, during endothermic sorbent regeneration in the calciner, CO 2 is released consequently. The CaL technology has proven its feasibility in semi-industrial scale by pilot testing in various test rigs all over the world. For the further development of the process, models are required for the prediction of process characteristics in terms of heat and mass flows. Most critical to the calculation of an overall process performance is the CO 2 absorption efficiency in the carbonator and, moreover, the decreasing CO 2 carrying capacity of the sorbent during operation. The enrichment of impurities like ash or calcium sulfate in the circulating sorbent as well as the reduction in particle size due to attrition needs also to be taken into account when assessing the performance of a CaL system. The main focus of this paper is the development of an advanced steady state process model and its validation against 1 MW th long term pilot testing. The validation of the process model showed good agreement in predicting the CO 2 absorption efficiency of the carbonator as well as the sorbent regeneration in calciner. Furthermore, the composition, and the effect of attrition to particle size distribution of the circulating sorbent are reproduced with good accordance. The process model is further applied for a sensitivity study to show the influence of crucial parameters on the particle size reduction as well as on the calciner efficiency. [ABSTRACT FROM AUTHOR]

Among the key barriers to commercial scale deployment is the cost associated with CO 2 capture. This is particularly true for existing large, fossil-fired assets that account for a large fraction of the electricity generation fleet in developed nations, including the U.S. Fitting conventional combustion technologies with CO 2 capture systems can carry an energy penalty of thirty percent or more, resulting in an increased price of power to the grid, as well as an overall decrease in net plant output. Taken together with the positive growth in demand for electricity, this implies a need for accelerated capital build-out in the power generation markets to accommodate both demand growth and decreased output at retrofitted plants. In this paper, the authors present the results of a study to assess the potential to use geothermal energy to provide boiler feedwater preheating, capturing efficiency improvements designed to offset the losses associated with CO 2 capture. Based on NETL benchmark cases and subsequent analysis of the application using site-specific data from the North Valmy power plant, several cases for CO 2 capture were evaluated. These included geothermally assisted MEA capture, CO 2 BOLs capture, and stand-alone hybrid power generation, compared with a baseline, no-geothermal case. Based on Case 10, and assuming 2.7 MMlb/h of geothermally sourced 150 °C water, the parasitic power load associated with MEA capture could be offset by roughly seven percent, resulting in a small (∼1 percent) overall loss to net power generation, but at levelized costs of electricity similar to the no-geothermal CCS case. For the CO 2 BOLs case, the availability of 150 ˚C geothermal fluid could allow the facility to not only offset the net power decrease associated with CO 2 BOLs capture alone, but could increase nameplate capacity by two percent. The geothermally coupled CO 2 BOLs case also decreases LCOE by 0.75 ¢/kWh relative to the non-hybrid CO 2 BOLs case, with the improved performance over the MEA case driven by the lower regeneration temperature and associated duty for CO 2 BOLs relative to MEA. [ABSTRACT FROM AUTHOR]

Since the early 2000's, there has been growing recognition of the important role that CCS can play as part of a least-cost, global solution to climate change. Modelling by the International Energy Agency (IEA) has consistently highlighted a significant role for CCS in achieving a 2 o C target, and recognition of the role of CCS has also increasingly been a feature of reports by the Intergovernmental Panel on Climate Change (IPCC). However, this growing appreciation of the value of CCS has not been accompanied by commensurate growth in political and policy support for the technology. In fact, support for CCS has been inconsistent and at times tumultuous, and has been closely intertwined with progress in global climate negotiations and wider economic conditions. CCS will not advance without significant public investment and the required support policies will not be put in place without political support – hence the politics of CCS play a major role in this respect. This paper looks at the politics of deploying large-scale CCS projects, including the drivers for CCS support, the opposing political forces and the practical challenges of deploying CCS. It will examine what factors could help to de-politicise CCS, and consider whether the Paris Agreement could provide a turning point. [ABSTRACT FROM AUTHOR]

Faster dissolution of CO 2 within aquifers plays a crucial role in the optimal storage of carbon dioxide injected into reservoirs. The mixture of CO 2 and brine triggers convection currents in the aquifer and creates a remarkable increase of the dissolution rate of carbon dioxide. It is very vital for the risk assessment of leakage to obtain accurate description of the CO 2 dissolution rate in the aquifers. In our experiments a series of CO 2 solute-driven convection laboratory tests were performed in transparent vertical Hele-Shaw cells with a 1.2 mm gap that contained brine water overlain by gas phase and visualization of convective phenomena was achieved with the help of bromocresol purple completely solved into the brine at first. After CO 2 -brine film come to existence, small phase fingers caused by density contrast would form and they merge, widen, and penetrate deep into the cell. Much series of images recording the dynamic convection were analyzed. Binarization process can help calculate timescale changes of average/all rich- CO 2 -area which present mass transfer rate of CO 2 into the brine. Effects of such different formation parameters as brine concentration, temperature, high pressure and heterogeneity on the onset and development of convection are investigated in our study. Two time intervals, including onset time and developing time took our most attention. Increasing system Rayleigh number, the formation parameters can greatly strengthen the convective mixing and accelerate the growth of CO 2 solution into the test cell. The sodium chloride solution concentration gradient has an obvious influence on the form and development of convection phenomenon in our experiments. Here, only part results are exhibited in this paper and much further work are under way. [ABSTRACT FROM AUTHOR]

The European Carbon Capture and Storage (CCS) industry is still grasping for an effective policy structure which will support deployment of commercial CCS projects. This paper will consider the current context of CCS policy given three significant developments: (a) the agreement in 2014 for a technology neutral 2030 EU emissions reduction target; (b) a binding commitment at COP21 in Paris, Dec 2015, for a global emissions reduction target; (c) the collapse of the UK's CCS Commercialisation Programme in Nov 2015. The period 2010-2015 saw continued stagnation in the European CCS industry, with a series of projects proposed but then subsequently cancelled. This hints as three problems (1) an industry which is weak in communicating why CCS is important, and failed to engage a wider stakeholder base; (2) incumbent governments which are not willing to fund the initially high costs of the first CCS projects; (3) weak market based structures which force industrial consortia to rely on government subsidy, thus leaving projects vulnerable to political forces. The tension within the UK's Commercialisation Programme could still offer lessons for other potential CCS projects in Europe; and inform policy developments at the UK and European level. Namely (i) payment flows between the emitter / capture plant to the transport & storage provider, and the risk apportionment between those partners; (ii) the cost-benefit of oversized infrastructure and the challenges of a first project to finance the bulk of these costs. A recent report to the UK government on CCS recommended state-owned companies delivering all aspects of CCS, but such a recommendation makes it all too easy for a centre-right party focussed on smaller government and tight expenditure to dismiss CCS as “too difficult”. An alternative would be normal commercial and market arrangements for the power & capture section; and a regulated monopoly for the transport & storage infrastructure, backed by the state for risk and liabilities. [ABSTRACT FROM AUTHOR]

India has a vast reserve of coal (∼ 7% of the world's total proved reserve) and is the third largest producer in the world. Almost 70% of the country's electrical power comes from the coal-fired thermal power plants. A few coalbed methane (CBM) projects have also commenced operations in the central and eastern parts of the country. However, CO 2 sequestration especially in geological formations is still at conceptual stage in India. Raniganj coalfield, located in the eastern states of West Bengal of Jharkhand is a repository of large reserves of high-volatile bituminous coals, where both mining and CBM operations are present. A number of coal-based thermal power plants are also located in the area, making this one of the most suitable areas for starting a carbon capture and storage (CCS) pilot project. CCS in unmineable coal seams arguably has the advantage of commercial success through potential release of additional methane when injected CO 2 adsorbs into the coal seams, the process known as enhanced coalbed methane (ECBM) recovery. However, a significant concern lies in the loss of injectivity due to reduction in permeability by coal matrix swelling with CO 2 adsorption although this effect can be partially be offset with ‘huff and puff’ scheme of cyclic CO 2 injection followed by extraction of the released methane. The paper discusses the results of a numerical simulation study carried out with GEM compositional reservoir simulator to evaluate the effects of uncertainties in various reservoir parameters on the overall volume of CO 2 storage and additional methane recovery before planning a pilot project in the Raniganj coalfield. A 3-m thick seam at 600 m depth was considered for fluid flow simulation study. While some information on the reservoir setting was obtained through literature and personal communication with the CBM operators, the rest of the information was derived through laboratory studies. The reservoir parameters considered for the study are injection pressure, adsorption capacity, permeability, cleat porosity, sorption time, and initial gas saturation. A 160-acre drainage area with 5-spot vertical well pattern was considered with one central injector and four producers on four corners of the study area. The maximum allowable injection pressure was estimated to be ∼ 850 psi (5856 kPa) at the reservoir setting. The injection pressure was varied from 300 psi (2067 kPa) to 850 psi (5856 kPa) in the simulation and 600 psi (4134 kPa) was found to be the optimum injection pressure. A number of adsorption isotherms on coals of Raniganj coalfield were established in the laboratory. The variations in the adsorption parameters observed through the isotherms were considered as uncertainty in the storage capacities. Significant variations were observed due to the variation in adsorption isotherms both for CO 2 storage and additional methane recovery. Fracture permeability was varied from 3 md to 40 md, which is the range of permeability observed in the coalfield. The results of simulation indicate a strong influence of permeability on the CO 2 storage and ECBM recovery. In the absence of specific information on sorption time, it was theoretically varied from a very fast-desorbing coal (sorption time of 1 day) to an extremely slow-desorbing coal (sorption time 200 days). Since rate of desorption from the coal matrix and fracture permeability are rate-control parameters, for each sorption time a low and a high permeability situation were considered. Fluid flow simulation study shows that variation in sorption time has no significant effect for a low permeability situation while some marginal effect in high permeability situation. Cleat porosity was varied from 0.5% to 1.5%. Within this range of porosities, enhanced methane recovery varied from 70% to 85% relative to the primary recovery but the volume of stored CO 2 did not vary significantly. Lastly, the initial gas saturation was varied from 70% to almost 100% and both the CO 2 sequestered volume and additional methane recovery were found to increase substantially. [ABSTRACT FROM AUTHOR]

In order to build confidence in CO 2 storage as greenhouse gas control activity, it is vital to learn from the experience gained from first-mover projects, at the pilot scale and at the demonstration scale. Many of the early CCS projects have published their findings with a view to supporting technology development for CO 2 storage, giving improved quality and accuracy in forecasting CO 2 -storage site behaviour. In order to build on these initial insights, we propose developing a comprehensive set of reference datasets designed to address specific uncertainties and technology gaps. This paper describes examples of how existing datasets have been used and identifies new and emerging technical issues that could be addressed using a broader set of reference datasets as part of an International CO 2 Storage Dataset Consortium. The datasets presented here show some of the insights gained so far into: well injectivity, down-hole pressure monitoring, flow modelling of CO 2 -brine systems, the geomechanical response to CO 2 injection and analysis of microseismic monitoring data. [ABSTRACT FROM AUTHOR]

In this paper, we revisit the marine controlled-source electromagnetic (CSEM) data, acquired above the Sleipner CO2 storage, in order to further study the dataset and conclude the feasibility of marine CSEM for offshore CCS monitoring. There are some challenges with respect to CSEM in this particular area: 1) strong airwave influence (due to regional shallow water depth); 2) potential of weak resistivity anomaly; 3) seabed pipeline network; and 4) rather shallow target depth. We are yet able to extract useful information; interpret further the CSEM inversion results by combining seismic data; and to extract the in situ resistivity and saturation of CO2 in the Utsira formation by applying a rock physics model. In addition, to minimize the influence of the seabed pipeline on the CSEM data, we have muted some of data and receivers near the seabed pipeline network. The results show a good agreement with seismic data, and the estimated total mass of CO2 agrees well with the injection data. This current study confirms that the marine CSEM can be an important and essential tool for offshore CO2 storage monitoring, yet not alone but when combined with both seismic and gravity. Finally, near-future large-scale CCS projects in the North Sea would require extensive infra-structures such as seabed pipeline, etc. This study demonstrates that CSEM may work even with such infra-structures in place. [ABSTRACT FROM AUTHOR]

Public acceptance is critical to the successful implementation of geologic CO 2 storage projects. As such, the U.S. Department of Energy mandated that project-based outreach be included in its regional partnerships as part of its Regional Carbon Sequestration Partnership Initiative. In 2003, the Plains CO 2 Reduction (PCOR) Partnership initiated a multifaceted, multilevel outreach program in tandem with its characterization and demonstration activities in the north central portion of North America. This paper discusses the role of outreach in the PCOR Partnership, methods employed, and select lessons learned over 13 years of doing public outreach. [ABSTRACT FROM AUTHOR]

The Tomakomai CCS demonstration project is currently being undertaken by the Japanese government in Tomakomai City, Hokkaido Prefecture, Japan. The project is scheduled to run between the period of JFY (*) 2012 - 2020 to demonstrate the viability of a full chain CCS system, from CO 2 capture to injection and storage. One hundred thousand tonnes per year or more of CO 2 derived from an industrial source will be injected and stored in saline aquifers under the seabed in the offshore area of Tomakomai Port. CO 2 injection began in April 2016. This paper outlines the demonstration plan and reviews the progress of the project. (*JFY denotes April of calendar year to March of following year) [ABSTRACT FROM AUTHOR]

Many studies in the literature optimise operation of individual components along the CCS process chain for base-load/design conditions. This fails to acknowledge the need for flexible operation of fossil CCS infrastructure in future low carbon energy systems, characterised by high shares of inflexible nuclear power and intermittent renewable power supply. In this environment CCS power stations are likely to be required to load-follow in order to balance the electricity grid. This results in extensive ramping and part-load operation as well as large variations in CO 2 flows that are produced. Unless CO 2 flow balancing techniques are deployed within the power stations, the CO 2 transportation and storage (T&S) systems will need to accommodate these large fluctuations in feed-flows. This paper addresses an identified gap in the literature by exploring the issues associated with flexible operation of CO 2 T&S systems, as well as options to overcome these issues. A particular focus is laid on the operational flexibility of injection wells as the potentially least flexible part of the system. [ABSTRACT FROM AUTHOR]

The Quest Carbon Capture and Storage (CCS) project in Alberta, Canada, is a fully integrated project, as it involves the capture, transport, injection, storage of CO 2 , and a measurement, monitoring and verification (MMV) program. The MMV program has two key objectives: a) to ensure containment and b) to ensure conformance. Prior to the start of CO 2 injection at the end of August 2015, a number of projects were undertaken to gather data from various domains, namely the atmosphere, biosphere, hydrosphere and geosphere, to provide input to the Quest MMV program. The focus of this paper is on monitoring activities undertaken in relation to the atmosphere and biosphere domains. Activities undertaken across the Quest sequestration lease area (SLA) included an eddy covariance system, soil gas probes, soil flux chambers, and walk-over surveys. In conclusion, understanding the spatial and temporal variability of CO 2 levels prior to start of CO 2 injection represents an important activity of a CCS MMV program. It provides technical input to the development of such a program, but also provides knowledge for communication to and awareness of project stakeholders (e.g. landowners) regarding CO 2 levels within the atmosphere and biosphere across a SLA. [ABSTRACT FROM AUTHOR]

Defining the ideal suite of monitoring technologies to be deployed at a carbon capture and storage (CCS) site presents a challenge to project developers, financers, insurers, regulators and other stakeholders. The monitoring, verification, and accounting (MVA) toolkit offers a suite of technologies to monitor an extensive range of parameters across a wide span of spatial and temporal resolutions, each with their own degree of sensitivity to changes in the parameter being monitored. Understanding how best to optimize MVA budgets to minimize the time to leak detection could help to address issues around project risks, and in turn help support broad CCS deployment. This paper presents a case study demonstrating an application of the Designs for Risk Evaluation and Management (DREAM) tool using an ensemble of CO 2 leakage scenarios taken from a previous study on leakage impacts to groundwater. Impacts were assessed and monitored as a function of pH, total dissolved solids (TDS), and trace metal concentrations of arsenic (As), cadmium (Cd), chromium (Cr), and lead (Pb). Using output from the previous study, the DREAM tool was used to optimize monitoring system designs based on variable sampling locations and parameters. The algorithm requires the user to define a finite budget to limit the number of monitoring wells and technologies deployed, and then iterates well placement, sensor type and location until it converges on the configuration with the lowest time to first detection of the leak averaged across all scenarios. To facilitate an understanding of the optimal number of sampling wells, DREAM was used to assess the marginal utility of additional sampling locations. Based on assumptions about monitoring costs and replacement costs of degraded water, the incremental cost of each additional sampling well can be compared against its marginal value in terms of avoided aquifer degradation. Applying this method, DREAM identified the most cost-effective ensemble with 14 monitoring locations. While this preliminary study applied relatively simplistic cost and technology assumptions, it provides an exciting proof-of-concept for the application of DREAM to questions of cost-optimized MVA system design that are informed not only by site-specific costs and technology options, but also by reservoir simulation results developed during site characterization and operation. [ABSTRACT FROM AUTHOR]

Engagement with the public is a critical element of ensuring the viability of CO 2 geologic storage (GS) projects. But there are fundamental differences among the types of projects that result in subsurface CO 2 storage; when it comes to outreach, one size may not fit all. This paper outlines the attributes for a deep saline storage project (Aquistore) in Canada with research projects related to two commercial CO 2 EOR projects using anthropogenic CO 2 –one in Canada (Weyburn–Midale) and one in the United States (Bell Creek)–compares their basic outreach configuration and then explores key aspects of public engagement within this framework. [ABSTRACT FROM AUTHOR]

This paper describes Phase I of the World Bank Group's (WBG) technical assistance project for the development of carbon capture, utilization and storage (CCUS) in Mexico. Phase I was concluded in early 2016 and saw the completion of three studies: 1. A pre-feasibility study of a proposed post-combustion capture (PCC) pilot plant at a natural gas-fired combined-cycle (NGCC) power plant in Mexico. This study, carried out by NEXANT Inc. under a consultant's assignment from the WBG, included a comparative techno-economic evaluation of six advanced amine-based PCC technologies and a generic amine-based conceptual pilot plant design. 2. A review of state-of-the-art practices related to combining carbon dioxide-enhanced oil recovery (CO 2 -EOR) with geological storage of CO 2 in Mexico. Specifically, this review, conducted by the Battelle Memorial Institute under a consultant's assignment from the WBG, assessed the requirements a CO 2 -EOR project must satisfy in order to qualify as a permanent storage project and earn carbon credits. 3. A study of the development of a CCUS regulatory framework for Mexico. This study, prepared by Milieu Ltd. under a consultant's assignment from the WBG, undertook a comprehensive and in-depth assessment of the current regulatory framework in Mexico as it pertains to CCUS, identified critical gaps and barriers that are expected to impede the development and implementation of CCUS, and made a series of recommendations for overcoming these and barriers. These three studies, funded by the WBG administered Trust Fund for Carbon Capture and Storage Capacity Building in Developing Countries (WB CCS TF), form the foundation for further work and will benefit the implementation of the planned pilot projects. The subject studies were also important for building capacity, increasing the awareness of CCUS among the various stakeholders in CCUS and building up their capacity, in line with the objectives of the WB CCS TF. [ABSTRACT FROM AUTHOR]

This paper presents a study into the possibility to enhance dissolution of CO 2 in brine using nanoparticles (NPs) as a remediation and/or mitigation option for unwanted migration of CO 2 . The idea is to inject a homogeneous mixture of NPs and CO 2 into the stored CO 2 . The heavier NP-CO 2 mixture spreads on the interface between the CO 2 and brine. The heavier NPs move into the brine together with the CO 2 and increase the density of the brine. This will enhance the process of convective mixing which increases the dissolution rate of CO 2 . However, it was found that the method is inefficient in terms of the amount of NPs needed compared to the increase in CO 2 dissolution. For example, to achieve an increase of 50% in the CO 2 dissolution rate, 1 kg of NP is needed to dissolve 3 kg extra CO 2 for an example case at 1 km depth. This makes the method unattractive both technically and economically: a large effort is required for engineering NPs with the correct properties, the risks associated are clogging and pressure increase, and the method is expensive. [ABSTRACT FROM AUTHOR]

The injection of supercritical CO 2 into the deep underground increases the pore pressure in the geologic formation, first locally around the injection point, later spreads radially throughout the formation. The range of pressure increase depends on the injection rate, injectivity and reservoir volume. The increase of pressure in the reservoir may cause several problems, including fracturing of sealing layer, fault reactivation and changes in other hydrogeological conditions. In order to reduce the pressure buildup in the reservoir during CO 2 injection, two methods were studied in this paper by numerical simulations using the TOUGH2 code. One describes production of formation water as proposed by Buscheck et al. in 2014 (dual-mode well), and the second method describes production of formation water via a second well during CO 2 injection. We employed a simple reservoir model based on available data of the CCS demonstration project at the Tomakomai area in Hokkaido, Japan. The efficiency and influence of two reservoir volumes, and a hypothetical placed production well, on pressure build-up in the storage formation were tested. Two models with different volumes, and an injection rate of 1 Mt/yr were applied and three cases were simulated for each model. The first case only considered injection of CO 2 for 100 years without production. The second case examined the dual-mode well, in which formation water was produced for 5 years prior to the start of CO 2 injection for 100 years. The last (third) case assumed utilization of an observation well for producing water in parallel with CO 2 injection. Judging from the results, the following conclusion can be drawn: 1) The dual-mode well with short duration of water production (5 years) was not so effective to maintain the reservoir pressure in the large reservoir volume considered here. The method would be better suited for smaller reservoir, otherwise a very long-term production would be necessary. 2) Water production in parallel with injection was very effective in order to maintain the reservoir pressure and to avoid harmful effects on the overlying seal layers and other hydrogeological conditions. The methods can be applied to make CCS technology much more sufficient through increasing the effective capacity of injectable CO 2 . It may also lead to more opportunities related to site selection. However, it has to be emphasized, that the effectiveness of the production strategies investigated here may highly depend on site conditions. Therefore, the results obtained in this study should be regarded as a preliminary evaluation for the Tomakomai site specifications. Further investigations would be necessary, when more data become available through the site investigation and even operations. [ABSTRACT FROM AUTHOR]

There have been many field carbon capture test facilities operated around the world over the last decade or so with a view to technology development and demonstrating and reducing capture cost to make CCS cost effective. A wide range of conventional and emerging technologies are undergoing tests by CO2CRC Limited (CO2CRC), using real feed gas from a variety of processes. Although learning by doing is the main motive for most of these tests, some went through systematic programs to step up the TRL ladder towards commercial readiness. This paper reports the results of each test facility to show the extent of learnings. [ABSTRACT FROM AUTHOR]

The concept of ‘unburnable carbon’ emerged in 2011, and stems from the observation that if all known fossil fuel reserves are extracted and converted to CO 2 (unabated), it would exceed the carbon budget and have a very significant effect on the climate. Therefore, if global warming is to be limited to the COP21 target, some of the known fossil fuel reserves should remain unburnt. Several recent reports have highlighted the scale of the challenge, drawing on scenarios of climate change mitigation and their implications for the projected consumption of fossil fuels. Carbon Capture and Storage (CCS) is a critical and available mitigation opportunity and its contribution to timely and cost-effective decarbonisation of the energy system is widely recognised. However, while some studies have considered the role of CCS in enabling access to more fossil fuels, no detailed analysis on this issue has been undertaken. This paper presents a critical review focusing on the technologies that can be applied to enable access to, or ‘unlock’, fossil fuel reserves in a way that will meet climate targets and mitigate climate change. It also quantifies the impact of CCS in unlocking unburnable carbon in the first and in the second half of the century. [ABSTRACT FROM AUTHOR]

Oxygen-fired combustion in circulating fluidized bed has been extensively studied during the last decade in different experimental scales from small laboratory devices to large pilot units. The development and scaling up of a new combustion technology require both experimental and modelling work. This paper summarizes the tests carried out at CIUDEN's 30 MWth oxy-CFB facility. The test data has been applied to validate a semi-empirical three-dimensional process model of the furnace. The 3D-model has been applied for predicting the performance of full scale oxy-CFB units: first a 300 MWe Flexi-Burn® CFB operated in air-fired and oxygen-fired modes and then a 600 MWe oxy-CFB with 40%-vol inlet oxygen concentration. Based on the experience of oxy-CFB tests at CIUDEN and model results of commercial scale units, there are no technological barriers which would prevent application of oxy-CFB based carbon capture and storage. [ABSTRACT FROM AUTHOR]