Relevant bibliographies by topics / Cost Assessment of CCS

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Academic literature on the topic 'Cost Assessment of CCS'

Author: Grafiati
Published: 1 July 2021
Last updated: 11 February 2022

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Journal articles on the topic "Cost Assessment of CCS"

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Hiremath, Mitavachan, Peter Viebahn, and Sascha Samadi. "An Integrated Comparative Assessment of Coal-Based Carbon Capture and Storage (CCS) Vis-à-Vis Renewable Energies in India’s Low Carbon Electricity Transition Scenarios." Energies 14, no. 2 (2021): 262. http://dx.doi.org/10.3390/en14020262.

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Roadmaps for India’s energy future foresee that coal power will continue to play a considerable role until the middle of the 21st century. Among other options, carbon capture and storage (CCS) is being considered as a potential technology for decarbonising the power sector. Consequently, it is important to quantify the relative benefits and trade-offs of coal-CCS in comparison to its competing renewable power sources from multiple sustainability perspectives. In this paper, we assess coal-CCS pathways in India up to 2050 and compare coal-CCS with conventional coal, solar PV and wind power sources through an integrated assessment approach coupled with a nexus perspective (energy-cost-climate-water nexus). Our levelized costs assessment reveals that coal-CCS is expensive and significant cost reductions would be needed for CCS to compete in the Indian power market. In addition, although carbon pricing could make coal-CCS competitive in relation to conventional coal power plants, it cannot influence the lack of competitiveness of coal-CCS with respect to renewables. From a climate perspective, CCS can significantly reduce the life cycle GHG emissions of conventional coal power plants, but renewables are better positioned than coal-CCS if the goal is ambitious climate change mitigation. Our water footprint assessment reveals that coal-CCS consumes an enormous volume of water resources in comparison to conventional coal and, in particular, to renewables. To conclude, our findings highlight that coal-CCS not only suffers from typical new technology development related challenges—such as a lack of technical potential assessments and necessary support infrastructure, and high costs—but also from severe resource constraints (especially water) in an era of global warming and the competition from outperforming renewable power sources. Our study, therefore, adds a considerable level of techno-economic and environmental nexus specificity to the current debate about coal-based large-scale CCS and the low carbon energy transition in emerging and developing economies in the Global South.
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Li, Jiaquan, Yunbing Hou, Pengtao Wang, and Bo Yang. "A Review of Carbon Capture and Storage Project Investment and Operational Decision-Making Based on Bibliometrics." Energies 12, no. 1 (2018): 23. http://dx.doi.org/10.3390/en12010023.

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The research on carbon capture and storage (CCS) project planning and investment and operational decision-making can provide a reference for enterprises to invest in CCS and for policy-makers to formulate policies to promote CCS development. So what are the current research hotspots in this field and the gaps that still need to be further studied in the future? This paper reviews the research in the field by a bibliometric analysis. The results show that the research in this field first focus on cost analysis, followed by project investment evaluation, project planning (cost curve and pipeline network), and project operation. In particular, fossil fuel power plants, pipeline transportation, and oil fields are the most crucial objects in the three technical links of CCS projects, respectively. Policies, carbon pricing, and uncertainty in cost and benefits are factors that are mainly discussed in this field. The methods used for CCS project planning are cost curve model and optimization model. The real option approach is suitable for the evaluation of investment decision-making. The evaluation of operational decision is mostly based on optimization model. The future research directions can be summarized as five points: (1) continuously and systematically update the calculated costs in the current research to the unified price of the latest year; (2) calculate the cost curve from the perspective of emission sources; (3) expand the planning region of pipeline network to the country, continent, and even the entire world; (4) pay more attention to the investment assessment of the CCS project that may be implemented with low cost and high return; and (5) analyze the optimal operation mode of CCS in the low-load power system.
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Szima, Szabolcs, Carlos Arnaiz del Pozo, Schalk Cloete, et al. "Techno-Economic Assessment of IGCC Power Plants Using Gas Switching Technology to Minimize the Energy Penalty of CO2 Capture." Clean Technologies 3, no. 3 (2021): 594–617. http://dx.doi.org/10.3390/cleantechnol3030036.

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Cost-effective CO2 capture and storage (CCS) is critical for the rapid global decarbonization effort recommended by climate science. The increase in levelized cost of electricity (LCOE) of plants with CCS is primarily associated to the large energy penalty involved in CO2 capture. This study therefore evaluates three high-efficiency CCS concepts based on integrated gasification combined cycles (IGCC): (1) gas switching combustion (GSC), (2) GSC with added natural gas firing (GSC-AF) to increase the turbine inlet temperature, and (3) oxygen production pre-combustion (OPPC) that replaces the air separation unit (ASU) with more efficient gas switching oxygen production (GSOP) reactors. Relative to a supercritical pulverized coal benchmark, these options returned CO2 avoidance costs of 37.8, 22.4 and 37.5 €/ton (including CO2 transport and storage), respectively. Thus, despite the higher fuel cost and emissions associated with added natural gas firing, the GSC-AF configuration emerged as the most promising solution. This advantage is maintained even at CO2 prices of 100 €/ton, after which hydrogen firing can be used to avoid further CO2 cost escalations. The GSC-AF case also shows lower sensitivity to uncertain economic parameters such as discount rate and capacity factor, outperforms other clean energy benchmarks, offers flexibility benefits for balancing wind and solar power, and can achieve significant further performance gains from the use of more advanced gas turbine technology. Based on all these insights, the GSC-AF configuration is identified as a promising solution for further development.
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Slavu, Nela, and Cristian Dinca. "Economical aspects of the CCS technology integration in the conventional power plant." Proceedings of the International Conference on Business Excellence 11, no. 1 (2017): 168–80. http://dx.doi.org/10.1515/picbe-2017-0018.

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Abstract One of the way to reduce the greenhouses gases emissions generated by the fossil fuels combustion consists in the Carbon Capture, Transport and Storage (CCS) technologies utilization. The integration of CCS technologies in the coal fired power plants increases the cost of the energy generation. The CCS technology could be a feasible solution in the case of a high value of a CO2 certificate but for the present value an optimization of the CCS technology integration in the power plants is expected. However, for reducing the cost of the energy generated in the case of CCS integration in the power plants, a parametrical study optimization of the CO2 capture process is required. In this study, the chemical absorption process was used and the monoethanolamine with 30 wt. %. The objective of this paper is to analyze the effects of the package type used in the absorption column on the size of the equipment used and, on the energy cost of the power plant with CO2 capture process consequently. The packages types analyzed in this paper are metal Pall rings with different sizes and the rings are made of different metals: aluminum, nickel, cooper, and brass. In the case of metal Pall rings, the utilization of different material has an impact on the absorption column weight. Also, Pall rings made of plastics (polypropylene and polyethylene) were analyzed. The comparative assessment was achieved for a coal fired power plant with an installed power of 100 MW and considering the CO2 capture process efficiency of 90 %.
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Hooper, B., B. Koppe, and L. Murray. "COMMERCIAL AND TECHNICAL ISSUES FOR LARGE-SCALE CARBON CAPTURE AND STORAGE PROJECTS—A GIPPSLAND BASIN STUDY." APPEA Journal 46, no. 1 (2006): 435. http://dx.doi.org/10.1071/aj05025.

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The Latrobe Valley in Victoria’s Gippsland Basin is the location of one of Australia’s most important energy resources—extremely thick, shallow brown coal seams constituting total useable reserves of more than 50,000 million tonnes. Brown coal has a higher moisture content than black coal and generates more CO2 emissions per unit of useful energy when combusted. Consequently, while the Latrobe Valley’s power stations provide Australia’s lowest- cost bulk electricity, they are also responsible for over 60 million tonnes of CO2 emissions per year—over half of the Victorian total. In an increasingly carbon constrained world the ongoing development of the Latrobe Valley brown coal resource is likely to require a drastic reduction in the CO2 emissions from new coal use projects—and carbon capture and storage (CCS) has the potential to meet such deep cuts. The offshore Gippsland Basin, the site of major producing oil and gas fields, has the essential geological characteristics to provide a high-volume, low-cost site for CCS. The importance of this potential to assist the continuing use of the nation’s lowest-cost energy source prompted the Australian Government to fund the Latrobe Valley CO2 Storage Assessment (LVCSA).The LVCSA proposal was initiated by Monash Energy (formerly APEL, and now a 100% subsidiary of Anglo American)—the proponent of a major brown coal-to-liquids plant in the Latrobe Valley. Monash Energy’s plans for the 60,000 BBL per day plant include CCS to store about 13 million tonnes of CO2 per year. The LVCSA, undertaken for Monash Energy by the Cooperative Research Centre for Greenhouse Gas Technologies (CO2CRC), provides a medium to high-level technical and economic characterisation of the volume and cost potential for secure geosequestration of CO2 produced by the use of Latrobe Valley brown coal (Hooper et al, 2005a). The assessment’s scope includes consideration of the interaction between CO2 injection and oil and gas production, and its findings have been publicly released for use by CCS proponents, oil and gas producers and all other interested parties as an executive summary, (Hooper et al, 2005b), a fact sheet (Hooper et al, 2005c) and a presentation (Hooper et al, 2005d)).The LVCSA identifies the key issues and challenges for implementing CCS in the Latrobe Valley and provides a reference framework for the engagement of stakeholders. In effect the LVCSA constitutes a pre-feasibility study for the implementation of geosequestration in support of the continuing development of Victoria’s brown coal resources.The LVCSA findings indicate that the Gippsland Basin has sufficient capacity to safely and securely store large volumes of CO2 and may provide a viable means of substantially reducing greenhouse gas emissions from coal-fired power plants and other projects using brown coal in the Latrobe Valley. The assessment also indicates that CO2 injection could well be designed to avoid any adverse impact on adjacent oil and gas production, so that CO2 injection can begin near fields that have not yet come to the end of their productive lives. However, CCS proposals involving adjacent injection and production will require more detailed risk management strategies and continuing cooperation between prospective injectors and existing producers.
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Payton, Ryan L., Mark Fellgett, Brett L. Clark, Domenico Chiarella, Andrew Kingdon, and Saswata Hier-Majumder. "Pore-scale assessment of subsurface carbon storage potential: implications for the UK Geoenergy Observatories project." Petroleum Geoscience 27, no. 2 (2021): petgeo2020–092. http://dx.doi.org/10.1144/petgeo2020-092.

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The growing importance of subsurface carbon storage for tackling anthropogenic carbon emissions requires new ideas to improve the rate and cost of carbon capture and storage (CCS) project development and implementation. We assessed sandstones from the UK Geoenergy Observatories (UKGEOS) site in Glasgow, UK and the Wilmslow Sandstone Formation (WSF) in Cumbria, UK at the pore scale to indicate suitability for further assessment as CCS reservoirs. We measured porosity, permeability and other pore geometry characteristics using digital rock physics techniques on microcomputed tomographic images of core material from each site. We found the Glasgow material to be unsuitable for CCS due to very low porosity (up to 1.65%), whereas the WSF material showed connected porosity up to 26.3% and permeabilities up to 6040 mD. Our results support the presence of a percolation threshold at 10% total porosity, introducing near full connectivity. We found total porosity varies with permeability with an exponent of 3.19. This provides a reason to assume near full connectivity in sedimentary samples showing porosities above this threshold without the need for expensive and time-consuming analyses.Supplementary material: Information about the boreholes sampled in this study, additional well logs of boreholes and a summary of the supporting data plotted throughout this article from literature are available at https://doi.org/10.6084/m9.figshare.c.5260074Thematic collection: This article is part of the Geoscience for CO2 storage collection available at: https://www.lyellcollection.org/cc/geoscience-for-co2-storage
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Cao, Cheng, Hejuan Liu, Zhengmeng Hou, Faisal Mehmood, Jianxing Liao, and Wentao Feng. "A Review of CO2 Storage in View of Safety and Cost-Effectiveness." Energies 13, no. 3 (2020): 600. http://dx.doi.org/10.3390/en13030600.

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The emissions of greenhouse gases, especially CO2, have been identified as the main contributor for global warming and climate change. Carbon capture and storage (CCS) is considered to be the most promising strategy to mitigate the anthropogenic CO2 emissions. This review aims to provide the latest developments of CO2 storage from the perspective of improving safety and economics. The mechanisms and strategies of CO2 storage, focusing on their characteristics and current status, are discussed firstly. In the second section, the strategies for assessing and ensuring the security of CO2 storage operations, including the risks assessment approach and monitoring technology associated with CO2 storage, are outlined. In addition, the engineering methods to accelerate CO2 dissolution and mineral carbonation for fixing the mobile CO2 are also compared within the second section. The third part focuses on the strategies for improving economics of CO2 storage operations, namely enhanced industrial production with CO2 storage to generate additional profit, and co-injection of CO2 with impurities to reduce the cost. Moreover, the role of multiple CCS technologies and their distribution on the mitigation of CO2 emissions in the future are summarized. This review demonstrates that CO2 storage in depleted oil and gas reservoirs could play an important role in reducing CO2 emission in the near future and CO2 storage in saline aquifers may make the biggest contribution due to its huge storage capacity. Comparing the various available strategies, CO2-enhanced oil recovery (CO2-EOR) operations are supposed to play the most important role for CO2 mitigation in the next few years, followed by CO2-enhanced gas recovery (CO2-EGR). The direct mineralization of flue gas by coal fly ash and the pH swing mineralization would be the most promising technology for the mineral sequestration of CO2. Furthermore, by accelerating the deployment of CCS projects on large scale, the government can also play its role in reducing the CO2 emissions.
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Sanchez, Daniel L., Nils Johnson, Sean T. McCoy, Peter A. Turner, and Katharine J. Mach. "Near-term deployment of carbon capture and sequestration from biorefineries in the United States." Proceedings of the National Academy of Sciences 115, no. 19 (2018): 4875–80. http://dx.doi.org/10.1073/pnas.1719695115.

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Capture and permanent geologic sequestration of biogenic CO2 emissions may provide critical flexibility in ambitious climate change mitigation. However, most bioenergy with carbon capture and sequestration (BECCS) technologies are technically immature or commercially unavailable. Here, we evaluate low-cost, commercially ready CO2 capture opportunities for existing ethanol biorefineries in the United States. The analysis combines process engineering, spatial optimization, and lifecycle assessment to consider the technical, economic, and institutional feasibility of near-term carbon capture and sequestration (CCS). Our modeling framework evaluates least cost source–sink relationships and aggregation opportunities for pipeline transport, which can cost-effectively transport small CO2 volumes to suitable sequestration sites; 216 existing US biorefineries emit 45 Mt CO2 annually from fermentation, of which 60% could be captured and compressed for pipeline transport for under $25/tCO2. A sequestration credit, analogous to existing CCS tax credits, of $60/tCO2 could incent 30 Mt of sequestration and 6,900 km of pipeline infrastructure across the United States. Similarly, a carbon abatement credit, analogous to existing tradeable CO2 credits, of $90/tCO2 can incent 38 Mt of abatement. Aggregation of CO2 sources enables cost-effective long-distance pipeline transport to distant sequestration sites. Financial incentives under the low-carbon fuel standard in California and recent revisions to existing federal tax credits suggest a substantial near-term opportunity to permanently sequester biogenic CO2. This financial opportunity could catalyze the growth of carbon capture, transport, and sequestration; improve the lifecycle impacts of conventional biofuels; support development of carbon-negative fuels; and help fulfill the mandates of low-carbon fuel policies across the United States.
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Pelitari, Stavroula, Charlotte Hathaway, Dean Gritton, et al. "Impact and cost-effectiveness of formal gastroenterology outpatient referral Clinical Assessment Service." Frontline Gastroenterology 9, no. 2 (2017): 159–65. http://dx.doi.org/10.1136/flgastro-2017-100853.

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ObjectiveThe aim was to assess the financial and operational impact of our new gastroenterology referral pathway model on our services.DesignAn electronic ‘Clinical Assessment Service’ (CAS) proforma and an information platform were developed, and all data were analysed retrospectively.SettingRoyal Wolverhampton NHS Trust.Patients14 245 general practitioner (GP) referrals were received during January 2014–December 2016 with 9773 of them being triaged via our CAS.Main outcome measuresWe looked into patients’ clinical outcome along with departmental performance and finances.ResultsA new outpatient appointment was offered to 60.1% (n=5873) of the CAS referred patients. Endoscopic or radiological investigations were requested for 29.2% (n=2854) of patients prior to deciding on further management plan. Out of those, 27% (n=765) went on to receive another gastroenterology (GI) clinic appointment. The remaining 21.3% (n=2089) of the CAS patients were discharged back to their GP following initial investigations. 5.5% (n=538) were discharged back to primary care with a letter of advice, whereas 5.2% (n=509) were deemed inappropriate for GI clinic and were redirected to other specialists. Overall, 32% (n=3127) of patients were managed without a face to face consultation in the GI clinic. This corresponds to 3136 less outpatient appointments with estimated reduced expenditure by the Clinical Commissioning Group (CCG) of £481K. The 18-week performance and waiting times remained stable despite the increasing referral population. The DNA rate dropped from 14% pre to 8.5%.ConclusionsOur clinical assessment model has, in addition to the clinical benefits, a considerable positive financial impact to the health economy.
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Adu, Emmanuel, Y. D. Zhang, Dehua Liu, and Paitoon Tontiwachwuthikul. "Parametric Process Design and Economic Analysis of Post-Combustion CO2 Capture and Compression for Coal- and Natural Gas-Fired Power Plants." Energies 13, no. 10 (2020): 2519. http://dx.doi.org/10.3390/en13102519.

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For the envisaged large number of commercial-scale carbon capture and storage (CCS) projects that are to be implemented in the near future, a number of issues still need to be resolved, the most prominent being the large capital and operational costs incurred for the CO2 capture and compression process. An economic assessment of the capture and compression system based on optimal design data is important for CCS deployment. In this paper, the parametric process design approach is used to optimally design coal and natural gas monoethanolamine (MEA)-based post-combustion CO2 absorption–desorption capture (PCC) and compression plants that can be integrated into large-scale 550 MW coal-fired and 555 MW natural gas combined cycle (NGCC) power plants, respectively, for capturing CO2 from their flue gases. The study then comparatively assesses the energy performance and economic viabilities of both plants to ascertain their operational feasibilities and relative costs. The parametric processes are presented and discussed. The results indicate that, at 90% CO2 capture efficiency, for the coal PCC plant, with 13.5 mol.% CO2 in the inlet flue gas, at an optimum liquid/gas ratio of 2.87 kg/kg and CO2 lean loading of 0.2082 mol CO2/mol MEA, the CO2 avoidance cost is about $72/tCO2, and, for the NGCC PCC plant, with 4.04 mol.% CO2 in the inlet flue gas, at an optimum liquid/gas ratio of 0.98 kg/kg and CO2 lean loading of 0.2307 mol CO2/mol MEA, the CO2 avoidance cost is about $94/tCO2.
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Dissertations / Theses on the topic "Cost Assessment of CCS"

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Saleh, Mostafa, and Sandberg Anton Hedén. "IMPLEMENTATION OF OXYFUEL COMBUSTION IN A WASTE INCINERATION CHP PLANT : A Techno-Economic Assessment." Thesis, Mälardalens högskola, Akademin för ekonomi, samhälle och teknik, 2021. http://urn.kb.se/resolve?urn=urn:nbn:se:mdh:diva-55210.

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Global energy demand is predicted to rise in the coming decades, necessitating a shift to renewable energy sources to mitigate greenhouse gas emissions. However, due to the inability to supply renewable energy around the clock, it is estimated that only by adding an important technology, carbon capture and storage (CCS), it could be possible to reduce 80% of the 1990s greenhouse gas emissions. CCS aims to reduce anthropogenic carbon emissions by capturing CO2 from flue gases, transporting, and permanently storing or reutilizing industrially. The CCS approach includes three technologies: post-combustion capture, pre-combustion capture, and oxyfuel combustion, with the latter being the emphasis of this thesis. Based on the case study of Mälarenergi’s Refused-derived waste-fired CHP plant, this thesis investigates the viability of converting existing non-fossil fueled CHP plants to oxyfuel combustion. A thorough technical investigation based on analyzing the impact of oxyfuel combustion on system performance was conducted through system modeling using a process simulator, Aspen plus. The model in this thesis considers the development of an air separation unit (ASU), a CHP plant, and a cryogenic CO2 purification unit (CPU). All of which are validated through calibration and comparison with real-world data and similar work. To investigate the influence of employing oxyfuel combustion on the generation of both heat and electricity, two different scenarios were comprised, including recirculating flue gas before and after flue gas condensation. In addition, an analysis of the oxygen purity was conducted to assess the most optimal parameters with the least impact on system performance. Moreover, a detailed eco- nomic assessment comprising the costs of integrating oxyfuel combustion was also conducted. The findings of this thesis show that integrating waste incineration CHP plants with oxyfuel combustion for CO2 capture entails promising features under the condition of 97% oxygen purity and a flue gas recirculation system taking place after flue gas condensation. This is owing to (i) modest imposed energy penalty of approximately 8.7%, (ii) high CO2 recovery ratio, around 92.4%, (iii) total investment cost of approximately 554 M$ during a 20-year lifetime, and (iv) cost of captured CO2 of around 76 $/ton. Aside from system modeling, this thesis pre- sents an overview of the current state-of-the-art technology on the different separation and capture mechanisms. It is important to highlight that the goal of this thesis is not to provide a comprehensive review but rather to present an overall picture of the maturity of the different mechanisms. The findings point to the cryogenic separation mechanism as the most mature technology for both oxygen production and capturing of CO2 during oxyfuel combustion.
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Zanobetti, Francesco. "Development of a multi-objective optimisation approach for the assessment of techno-economical and environmental performances of pipeline-based Carbon Capture and Storage (CCS) systems." Master's thesis, Alma Mater Studiorum - Università di Bologna, 2021.

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It is widely recognized that Carbon Capture and Storage (CCS) may be playing a key role in decarbonising industrial and power generation processes and meeting net zero emission targets by 2050. However, the successful large-scale development of CCS is still hindered by a wide lack of reliable techno-economic and environmental assessment methodologies. In the present work, a CFD code developed by UCL Chemical Engineering, named PipeTech, was first used to simulate CO2 pipeline transport performances with respect to variations of main design and operational parameters. Based on these results, a multi-objective optimisation methodology for CCS pipelines is proposed to minimise economic and environmental footprints while reliably simulating fluid flow behaviour. Then, the Decision Maker (DM) is supposed to select one or more trade-offs that best suit his preferences. Three potentially most effective solutions were determined by applying the mathematical Level Diagrams technique. Uncertainty affecting CO2 transport cost modelling is assessed by employing a Monte Carlo simulation approach, which also provides the DM with a probabilistic tool to compare the different alternatives. Lastly, a quantitative methodology is applied to convert multi-criteria optimisation results in impact indicators weighting economic and environmental issues. Results were then compared with those given by the single minimisation of two additional indices. These are presented as a “CO2 avoided transport cost”, which considers an apparent transported flow rate decreased by emitted GHG expressed as CO2 equivalents, and as a “market-based transport cost”, which applies a carbon pricing to the greenhouse gas emissions according to carbon markets. Overall, this approach provided a route to flexibly weigh environmental and economic concerns according to DM preferences, whereas the two aggregated indices give a lower visibility to the environmental footprint of the system.
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Bøe, Lisbeth Jeanette. "Life cycle assessment of novel CCS technologies." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for energi- og prosessteknikk, 2013. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-22885.

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CO2 emissions from the combustion of fossil fuels are the largest sources of anthropogenic greenhouse gas emissions to the atmosphere. Carbon capture and storage (CCS) is one of the better options to mitigate these emissions and thereby limit global warming even while continuing the use of fossil fuels for power generation. As CCS increases the energy consumption of the power plant itself, there will be an increased use of fuel and therefore also increased environmental impacts connected to this. To calculate these impacts it is important to include the entire supply chain and life cycle of the power plant.This thesis involves a tiered hybrid life cycle assessment of natural gas- and coal power plants with chilled ammonia process (CAP) and sorption enhanced water-gas shift (SEWGS) capture technologies. These novel capture technologies are two of the least studied when it comes to environmental assessments. The results from this assessment are compared to two of the more studied capture technologies, post-combustion capture by monoethanolamine (MEA) and oxyfuel combustion capture.Both the CAP capture alternative and the SEWGS alternative have been shown to decrease the global warming potential (GWP) in a natural gas plant by 70%. For the coal-fired power plants, the CAP technology managed a decrease in GWP of 77% while the SEWGS technology showed a decrease of 77.5%. This decrease comes at a cost of other impact categories where for example the freshwater ecotoxicity potential (FETP) has an increase of 87-88% for both the CAP and SEWGS capture technologies in NGCC plants. This impact category has an increase of 25 and 22% for the CAP and SEWGS technologies in the coal-fired power plants.Compared to post-combustion capture by MEA and oxyfuel combustion capture, the results were clear on MEA being the least preferable option in an environmental perspective for both coal- and natural gas-fired power plants. Oxyfuel combustion capture, on the other hand, was shown to be the most preferable option.
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Djurberg, Robert. "Practical implementation of Bio-CCS in Uppsala : A techno-economic assessment." Thesis, KTH, Energiteknik, 2020. http://urn.kb.se/resolve?urn=urn:nbn:se:kth:diva-277820.

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To decrease global warming, bioenergy with carbon capture and storage (Bio-CCS) has been proposed as an effective and necessary tool. Combusting biomass and capturing carbon dioxide (CO2) from the same process results in net negative emissions, hence, reducing the concentration of CO2 in the atmosphere. The infrastructure around heat and power generation in Sweden has transformed to make use of biomass and waste. Bio-CCS has the potential to be a key factor in making the heat sector carbon negative and the Swedish energy system more sustainable. This study has assessed how Bio-CCS can practically be implemented in the Uppsala heat and power plant. In the assessment, three chemical absorption post-combustion carbon capture (CC) technologies were evaluated based on energy requirement, potential to reduce emissions and economics. They are the amine process, the chilled ammonia process (CAP) and the hot potassium carbonate process (HPC). The process of each technology was modelled by performing mass and energy balance calculations when implementing CC on the flue gas streams of the production units using biomass-based fuel at the plant. The modelling enabled finding specific heating, cooling and electricity requirements of the technologies. With this data it was possible to assess the potential emission reduction and CC cost for the different configurations assessed. A solution was proposed in how a CC technology can be integrated into the system of the Uppsala plant regarding land footprint, available heat supply to the process and possibilities for waste heat recovery. If heat recovery is not utilized the results show that the amine process is the most cost-effective technology when implemented on the flue gas stream of the waste blocks. When utilizing heat recovery to use waste heat to heat the district heating water, CAP becomes more cost-effective than the amine process. Further improvements can be achieved by combining flue gas streams of the waste blocks to increase the number of hours per year CC can be performed. The plant in Uppsala can then capture 200 000 tonne CO2 annually. The total cost of Bio-CCS will be approximately 900 SEK per tonne CO2 captured.<br>För att minska den globala uppvärmningen har infångning och lagring av koldioxid från förbränning av biomassa (Bio-CCS) föreslagits som ett effektivt och nödvändigt verktyg. Förbränning av biomassa och infångande av koldioxid från samma process leder till negativa nettoutsläpp, vilket minskar koncentrationen av koldioxid (CO2) i atmosfären. Infrastrukturen kring värme- och kraftproduktion i Sverige har omvandlats till att använda biomassa och avfall. Bio-CCS har potential att vara en nyckelfaktor för att göra värmesektorn koldioxidnegativ och det svenska energisystemet mer hållbart. Denna studie har analyserat hur Bio-CCS praktiskt kan implementeras i Uppsalas kraftvärmeverk. I analysen utvärderades tre infångningstekniker av typen kemisk absorption baserat på energibehov, potential att minska utsläpp och ekonomi. Teknikerna är aminprocessen, chilled ammonia process (CAP) och hot potassium carbonate process (HPC). Processen för varje teknik modellerades genom att utföra mass- och energibalansberäkningar vid infångning av CO2 från rökgasströmmarna producerade av produktionsenheterna som förbränner biomassa. Modelleringen gjorde det möjligt att hitta specifika värme-, kyl- och elbehov för teknikerna. Med dessa data var det möjligt att bedöma den potentiella utsläppsminskningen och kostnaden för infångning för de olika konfigurationer som har analyserats. En lösning föreslogs i hur en infångningsanläggning kan integreras i kraftvärmeverkets system när det gäller markanvändning, tillgänglig värmeförsörjning till processen och möjligheter till återvinning av spillvärme. Om värmeåtervinning inte utnyttjas visar resultaten att aminprocessen är den mest kostnadseffektiva tekniken när den implementeras på rökgasströmmen från avfallsblocken. När man använder värmeåtervinning för att använda spillvärme för att värma fjärrvärmevattnet blir CAP mer kostnadseffektivt än aminprocessen. Ytterligare förbättringar kan uppnås genom att kombinera rökgasströmmar från avfallsblocken för att öka antalet timmar per år infångning kan utföras. Anläggningen i Uppsala kan då årligen fånga 200 000 ton CO2. Den totala kostnaden för Bio-CCS kommer att vara cirka 900 SEK per ton infångad CO2.
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Nyberg, Jesper. "Kostnaden för CCS vid Cementa AB i Degerhamn." Thesis, Linnéuniversitetet, Institutionen för biologi och miljö (BOM), 2016. http://urn.kb.se/resolve?urn=urn:nbn:se:lnu:diva-54270.

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CCS, Carbon Capture and Storage, innebär infångning och lagring av koldioxid från stora punktutsläpp. Detta gör cementindustrin aktuell för implementering av CCS. Stora delar av branschens koldioxidutsläpp går inte att eliminera på annat sätt. Kostnaden för monoetanolamin-baserad post-combustion capture med efterföljande transport och lagring av koldioxiden vid cementfabriken Cementa AB i Degerhamn undersöktes. Studiens kostnadsberäkningar är baserade på publicerade uppgifter om kostnaden för koldioxidinfångning vid den norska cementfabriken Norcem Brevik, och på publicerade uppgifter om kostnaden för transport av koldioxid till en lagringsplats i Östersjön. Cementa Degerhamns koldioxidutsläpp kan reduceras med 5,4 miljoner ton under en 25-årsperiod till en kostnad av 2,2 miljarder SEK. Slutresultatet, som uttrycks i måttet Cost of CO2 avoided, ger en kostnad på 890 SEK/ton CO2. En känslighetsanalys visar att av de undersökta parametrarna är storleken på koldioxidutsläppen och kostnaden för användning och underhåll viktigast för storleken på Cost of CO2 avoided. Vidare studier behövs för en mer exakt beräkning av kostnaden för CCS vid Cementa Degerhamn.<br>CCS, Carbon Capture and Storage, involves the capture and storage of carbon dioxide from large point sources. This makes the cement industry suitable for the implementation of CCS. Large parts of the industry's carbon dioxide emissions cannot be eliminated by other means. The cost of monoethanolamine-based post-combustion capture and subsequent transport and storage of the carbon dioxide at the cement factory Cementa AB in Degerhamn was studied. This study's cost estimates are based on published data on the cost of carbon capture at the Norwegian cement plant Norcem Brevik, and on published data on the cost of transport of carbon dioxide to a storage site in the Baltic Sea. Cementa Degerhamn’s carbon dioxide emissions can be reduced by 5.4 million tons over a 25 year period to a cost of 2.2 billion SEK. The result, expressed in Cost of CO2 avoided, gives a cost of 890 SEK/ton CO2. A sensitivity analysis shows that of the examined parameters, the size of the carbon dioxide emissions and the cost of use and maintenance are the most important for the size of Cost of CO2 avoided. Further studies are required for a more accurate calculation of the cost of CCS at Cementa Degerhamn.
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Occhineri, Lorenzo. "Technical and economic assessments of CO2 capture processes in power plants." Thesis, Mälardalens högskola, Akademin för hållbar samhälls- och teknikutveckling, 2008. http://urn.kb.se/resolve?urn=urn:nbn:se:mdh:diva-4705.

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Occhineri, Lorenzo. "Technical and economic assessments of CO2 capture processes in power plants." Thesis, Mälardalen University, School of Sustainable Development of Society and Technology, 2008. http://urn.kb.se/resolve?urn=urn:nbn:se:mdh:diva-4705.

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Johansson, Emma, and Vilborg Pétursdóttir. "Evaluation of Onshore Transportation Methods for Captured CO2 between Facility and Harbour in Stockholm." Thesis, KTH, Maskinkonstruktion (Avd.), 2021. http://urn.kb.se/resolve?urn=urn:nbn:se:kth:diva-297664.

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Carbon capture and storage (CCS) is a method to reduce the emission of CO2 into the atmosphere. Stockholm Exergi is a Stockholm based company with combined heat and power (CHP) plants in various places around the city and are currently investigating the possibilities to implement CCS on their CHP plant Högdalenverket. The captured CO2 is required to be transferred from the facility to a harbour for further transport to its injection site. This report investigates the optimal means of transportation from the facility to harbour. The methods considered are pipeline and trucks.From the frame of reference, it is concluded that the shortest distance possible is preferable, so the harbour alternative is set to be Värtan. For pipelines the cheapest alternative of the state of form, for the specific case, is gas. For trucks the best alternative is liquid since a larger amount can fit in each load. For the cost estimation the method from (Piessenset al., 2008) is used to calculate the price estimate of pipelines, and (Marufuzzaman, 2015) is used for the trucks. Parameters such as the diameter of the pipe, pressure drop and power requirement are of high importance for the pipeline. For truck road regulations, CO2’s density and operation time is essential. The results from the implementation shows the pipelines to be the more beneficial option in regards to price, stability and robustness. The NPV for the pipeline is calculated, with the lifetime of theproject as 25 years, to be 75 million €, which is the cheaper alternative compared to the truck, which has a NPV of 95 million €. The optimal inlet pressure for the pipes is calculated to be 3.5MPa and the temperature to be 57.5°C due to an implemented heat exchange operation before the inlet. Future work and recommendations are to continue creating a more detailed design over the pipelines and to discard the truck transport alternative.<br>Infångning och lagring av koldioxid (CCS) är en metod för att minska utsläppen av CO2 i atmosfären. Stockholm Exergi är ett energibolag i Stockholm med diverse kraftvärmeverk runtom i staden. En undersökning pågår där företaget forskar kring möjligheterna att implementera CCS på kraftvärmeverk Högdalenverket. Den uppfångade koldioxiden ska transporteras från anläggning till hamn, där den sedan ska vidare med skepp till sin injektionsplats. Denna rapport studerar vilken den optimala metoden för transport från anläggning till hamn är. Metoderna som berörs är rörledningar och lastbilar. Från bakgrundstudien var det möjligt att dra slutsatsen om att det kortaste möjliga avståndet är optimalt, så den valda hamnen är Värtahamnen. För rörledningarna är det billigaste alternativet på substansen gas för det behandlade fallet i rapporten. För lastbilsalternativet är den optimala formen vätska då det får plats mer volym per last. För uppskattningen av priserna används metoden från (Piessenset al., 2008) för rörledningarna och (Marufuzzaman, 2015) för lastbilarna. Parametrar såsom diametern på rören, tryckfall och effektkrav är viktiga för rörledningarna. För lastbilarna är vägkrav, CO2 s densitet och operationstid essentiella. Resultaten från implementationen visar att transport med rörledningar är det optimala alternativet i avseende av pris och stabilitet. Nuvärdet på investeringen av rörledningarna är beräknade till 75miljoner €, som är billigare jämfört med 95 miljoner € för lastbilsalternativet. Det optimala trycket för inloppet till rörledningarna är beräknat till 3.5 MPa och inloppstemperaturen till 57.5°C som resultat av en implementerad värmeväxlaroperation precis före starten på rörledningen. Framtida arbete och rekommendationer är att fortsätta utveckla en mer detaljerad design överrörledningen och att avfärda alternativet med transport av lastbilar.
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Silva, Wildson Vieira da. "ADAPTAÇÃO DA ESCALA AUSTRALIANA CHILDHOOD CONCERNS SURVEY (CCS) NUM CONTEXTO BRASILEIRO." Universidade Catolica de Pelotas, 2003. http://tede.ucpel.edu.br:8080/jspui/handle/tede/427.

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Made available in DSpace on 2016-03-22T17:27:43Z (GMT). No. of bitstreams: 1 Wildson.pdf: 615673 bytes, checksum: f76785a39c7bddef5788cf7c58944c34 (MD5) Previous issue date: 2003-12-22<br>Objective: To translate and to adapt the Childhood Concerns Survey (CCS), an Australian scale that evaluates anxiety disorders among preschoolers based on their parent s answers, with the intention of using it in the Brazilian children. Method: Two bilingual professionals translated two Portuguese versions of the scale, which were retro-translated by other tree bilingual professionals. The differences were harmonized and pre-tested in a pilot study. The final Portuguese version was applied by 420 parents of boys and girls between 2,5 to 6 years old from Pelotas. The CCS s psychometrical properties were tested. The Contend Validity was verified by the Theoretical Items Analysis and the Items Analysis by the Classic Tests Theory. For the extern criterion validity the ANOVA was utilized, considering age and sex. The Construct Validation study was made by the Exploratory Factor Analysis and Cronbach s alpha coefficient was used as reliability. Results: The Exploratory Factor Analysis indicated the presence of 4 factors reflecting Obsessive Compulsive Disorder, Fear of physical injury and Social Phobia and Generalized Anxiety Disorder. The ANOVA method revealed relevant differences p<0,05 between gender and age, demonstrating that girls had higher scores than boys. Conclusion: It was found necessary to reformulate the written composition of some items. The final version of the proposed scale to evaluate 4 anxiety disorders has 26 items and presents acceptable psychometric characteristics<br>Objetivo: Traduzir e adaptar o "Childhood Concerns Survey" (CCS), escala australiana que avalia transtornos de ansiedade em pré-escolares com base nas respostas dos pais, com a intenção de utilizá-la em crianças brasileiras. Método: Dois profissionais bilíngües traduziram duas versões da escala para o português, as quais foram retro-traduzidas por outros três profissionais bilíngües. As diferenças foram harmonizadas e pré-testadas em um estudo piloto. A versão final em português foi aplicada em 420 pais de crianças de ambos os sexos entre 2,5 a 6 anos da cidade de Pelotas-RS. Foram testadas as propriedades psicométricas do CCS. A validade de conteúdo por meio da análise teórica dos Itens e a capacidade discriminativa dos itens segundo a análise da correlação item/ total. Para a validade de critério externa utilizou-se a análise de variância (ANOVA) fatorial, considerando idade e sexo. A validade de construto foi realizada por meio da análise fatorial exploratória e utilizou-se como o coeficiente de fidedignidade o alfa de Cronbach. Resultados: A análise fatorial exploratória indicou a presença de 4 fatores refletindo transtorno obsessivo compulsivo, medo de lesão física, fobia social e transtorno de ansiedade generalizada. O método da ANOVA revelou diferenças significativas p<0,05 entre os sexos e idades, demonstrando que as meninas tiveram escores maiores que os meninos. Conclusão: Identificou-se a necessidade de reformular a redação de alguns itens. A versão final da escala proposta para avaliar 4 transtornos de ansiedade consta de 26 itens e apresenta características psicométricas aceitáveis
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Jonnavithula, Satish. "Cost/benefit assessment of power system reliability." Thesis, National Library of Canada = Bibliothèque nationale du Canada, 1997. http://www.collectionscanada.ca/obj/s4/f2/dsk3/ftp05/nq23942.pdf.

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Books on the topic "Cost Assessment of CCS"

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Office, Global Environment Facility Evaluation. Evaluation of incremental cost assessment. Global Environment Facility, Evaluation Office, 2007.

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Skaburskis, Andrejs. An assessment of development cost levies. Province of British Columbia, Ministry of Municipal Affairs, Recreation and Housing, 1993.

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Inc, St Lawrence Cement. Fuel cost reduction study/environmental assessment: Final environmental assessment document. St. Lawrence Cement, 1992.

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Baker, R. C. Reliability cost/worth assessment of composite systems. UMIST, 1995.

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Trendowicz, Adam. Software Cost Estimation, Benchmarking, and Risk Assessment. Springer Berlin Heidelberg, 2013. http://dx.doi.org/10.1007/978-3-642-30764-5.

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Edlin, Richard, Christopher McCabe, Claire Hulme, Peter Hall, and Judy Wright. Cost Effectiveness Modelling for Health Technology Assessment. Springer International Publishing, 2015. http://dx.doi.org/10.1007/978-3-319-15744-3.

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Holmes, Roy. Property condition assessment: A cost effective approach. Chartered Institute of Building, 1990.

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Kirlin, John A. Assessment of WIC cost-containment practices: Executive summary. U.S. Dept. of Agriculture, Economic Research Service, 2003.

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Kirlin, John A. Assessment of WIC cost-containment practices: Executive summary. U.S. Dept. of Agriculture, Economic Research Service, 2003.

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Kirlin, John A. Assessment of WIC cost-containment practices: Executive summary. U.S. Dept. of Agriculture, Economic Research Service, 2003.

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Book chapters on the topic "Cost Assessment of CCS"

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Chiang, Pen-Chi, and Shu-Yuan Pan. "Environmental Impact Assessment and CCS Guidance." In Carbon Dioxide Mineralization and Utilization. Springer Singapore, 2017. http://dx.doi.org/10.1007/978-981-10-3268-4_4.

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Macauley, Molly. "Cost Benefit Assessment." In Encyclopedia of Remote Sensing. Springer New York, 2014. http://dx.doi.org/10.1007/978-0-387-36699-9_22.

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Fleer, Johannes, and Wilhelm Kuckshinrichs. "Cost Analysis for CCS in Selected Carbon-Intensive Industries." In Carbon Capture, Storage and Use. Springer International Publishing, 2014. http://dx.doi.org/10.1007/978-3-319-11943-4_8.

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Billinton, Roy, and Wenyuan Li. "Reliability Cost/Worth Assessment." In Reliability Assessment of Electric Power Systems Using Monte Carlo Methods. Springer US, 1994. http://dx.doi.org/10.1007/978-1-4899-1346-3_7.

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Zeller, Gregory, Douglas A. Young, and Brian Novy. "The American Dental Association Caries Classification System (ADA CCS)." In Detection and Assessment of Dental Caries. Springer International Publishing, 2019. http://dx.doi.org/10.1007/978-3-030-16967-1_7.

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Kainuma, Mikiko, Yuzuru Matsuoka, Tsuneyuki Morita, Toshihiko Masui, and Kiyoshi Takahashi. "Cost Analysis of Mitigation Policies." In Climate Policy Assessment. Springer Japan, 2003. http://dx.doi.org/10.1007/978-4-431-53985-8_4.

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Perkins, Frances C. "Discounted project assessment criteria." In Practical Cost Benefit Analysis. Macmillan Education UK, 1994. http://dx.doi.org/10.1007/978-1-349-15186-8_5.

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Froud, Julie, Rebecca Boden, Anthony Ogus, and Peter Stubbs. "Compliance Cost Assessment in Action." In Controlling the Regulators. Palgrave Macmillan UK, 1998. http://dx.doi.org/10.1007/978-1-349-14632-1_3.

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Bot, Yizhak. "Reliability and Cost Optimization." In Probabilistic Safety Assessment and Management ’96. Springer London, 1996. http://dx.doi.org/10.1007/978-1-4471-3409-1_42.

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Emblemsvåg, Jan, and Bert Bras. "Environmental Management and Assessment." In Activity-Based Cost and Environmental Management. Springer US, 2001. http://dx.doi.org/10.1007/978-1-4419-8604-7_2.

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Conference papers on the topic "Cost Assessment of CCS"

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Gülen, S. Can, and Ann V. Driscoll. "Simple Parametric Model for Quick Assessment of IGCC Performance." In ASME Turbo Expo 2012: Turbine Technical Conference and Exposition. American Society of Mechanical Engineers, 2012. http://dx.doi.org/10.1115/gt2012-68301.

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Even though almost all components of an Integrated Gasification Combined Cycle (IGCC) power plant are proven and mature technologies, the sheer number of them, the wide variety of competing technologies (e.g., gasifiers, gas clean-up systems, heat recovery options), system integration options (e.g., cryogenic air separation unit and the gas turbine) including the recent addition of carbon capture and sequestration (CCS) with its own technology and integration options render fundamental IGCC performance analysis a monumental task. Almost all published studies utilize highly complex chemical process and power plant heat balance software, including commercially available packages and in-house proprietary codes. This makes an objective assessment of comparable IGCC plant designs, performance (and cost) and other perceived advantage claims (IGCC versus other technologies, too) very difficult if not impossible. This paper develops a coherent simplified parametric model based on fully physics-based grounds to be used for quick design performance assessment of a large variety of IGCC power plants with and without CCS. Technology parameters are established from complex model runs and supplemented by extensive literature search. The model is tested using published data to establish its confidence interval and is satisfactory to carry conceptual design analysis at a high level to identify promising alternatives, development areas and assess the realism in competing claims.
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Ennis, C. J., and K. K. Botros. "Thermodynamic and Economic Assessment of Oxy-Combustion CCS System Applied to Gas Turbine-Driven Compressor Stations." In 2010 8th International Pipeline Conference. ASMEDC, 2010. http://dx.doi.org/10.1115/ipc2010-31015.

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Government policies currently in place or in development will require the reduction of greenhouse gas emissions from industry, including gas transmission systems. Most of the natural gas transmission systems are powered by gas turbines of sizes up to 30 MW per unit. A typical gas turbine of this size can emit 6 ktonnes of CO2 per MW-year, equivalent to about 180 ktonnes per year. Reduction in greenhouse gas emissions can be accomplished through post-combustion systems (separation of CO2 from flue gases through chemical absorption, physical adsorption, membrane or cryogenic systems) or through oxy-fuel combustion, where fuel is combusted in pure O2 leading to sequestration of CO2 by compression and dehydration of the exhaust gases. The purpose of the current work is to explore the application of the latter concept, simplify and enhance the cycle, and to provide an economic valuation of the cost per tonne of CO2 abated. Innovations explored for enhancement include elimination of excess power production, simplification of capital equipment requirements, and optimization of the power to the booster produced from the gas turbine and steam turbine. The paper presents various innovation options arrived at, detailed thermodynamic parameters, and a cost and economic evaluation of these options. Particular emphasis was placed on the application of this technology to a typical compressor station on a natural gas transmission system as this application is vastly different than a typical power plant contemplating or employing carbon capture and storage (CCS) systems, most notably from the small power size, the remote location, and the self-containment perspectives.
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Wyss, Gregory D., John F. Clem, John L. Darby, Katherine Dunphy-Guzman, John P. Hinton, and Kim W. Mitchiner. "Risk-based cost-benefit analysis for security assessment problems." In 2010 IEEE International Carnahan Conference on Security Technology (ICCST). IEEE, 2010. http://dx.doi.org/10.1109/ccst.2010.5678687.

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Stoenescu, Ionut Bogdan, Sorina Costinas, and Gheorghe Marius Deaconu. "Assessment of Hydropower Plants Energy Production Cost Influenced by Operational Decisions and Control Strategy." In 2019 22nd International Conference on Control Systems and Computer Science (CSCS). IEEE, 2019. http://dx.doi.org/10.1109/cscs.2019.00062.

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Ahadi, Amir, Xiaodong Liang, and Weixing Li. "An analytical method for wind energy potential, reliability, and cost assessment for wind generation systems." In 2017 IEEE/IAS 53rd Industrial and Commercial Power Systems Technical Conference (I&CPS). IEEE, 2017. http://dx.doi.org/10.1109/icps.2017.7945126.

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Harto, Christopher, Ellen White, Robert Horner, and Jenna Schroeder. "Technology Choice and Water Consumption for Coal Electricity Production With Carbon Capture and Storage." In ASME 2014 Power Conference. American Society of Mechanical Engineers, 2014. http://dx.doi.org/10.1115/power2014-32178.

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Water consumption is an important consideration when evaluating technologies for carbon capture and storage (CCS). It may in fact become a critical factor in certain regions where water is increasingly a source of conflict. For this reason, water consumption has the potential to become a challenging obstacle to adoption of CCS technologies. This analysis seeks to improve understanding of relative water costs of different CCS technology options. It also helps to identify areas where water use may in fact become a challenge and reveal opportunities for technological improvements that can help minimize these challenges. A life cycle assessment approach was utilized to analyze both the water consumption from carbon capture and storage projects. While there have been previous analyses that have looked at the direct water consumption for some capture processes, there have been few studies that have taken a detailed look at water consumption throughout the complete life cycle of the of electricity production with CCS. This effort expands the system boundaries beyond those of previous analysis while evaluating a range of system configurations to facilitate technology comparison. The range of system configurations considered in this analysis included both pre and post combustion capture systems and multiple sequestration scenarios. The system boundaries for the analysis include fuel production, fuel transport, combustion, capture, CO2 transport, and storage. Water consumption for conventional fossil fuel systems are also calculated for comparison purposes. The results show that while all carbon capture technology pathways result in a net increase in water consumption relative to conventional coal generation, the choice of technology, especially capture technology, can play a significant role in minimizing the increase in water consumption. Integrated gasification combined cycle coal plants with carbon capture were found to be significantly more water efficient than either conventional power plants with post combustion capture or plants utilizing oxy-combustion processes. Also, while other stages of the life cycle do consume water, the volumes were small relative to the power plant operations and capture stages.
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Ghazi, Nima, and Julia M. Race. "Techno-Economic Modelling and Analysis of CO2 Pipelines." In 2012 9th International Pipeline Conference. American Society of Mechanical Engineers, 2012. http://dx.doi.org/10.1115/ipc2012-90455.

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The main focus of this paper is on techno-economic modeling and analysis of CO2 pipelines, as it strives to develop a thorough understanding of the essential fluid-mechanics variables involved in modeling and analysis of such pipelines. The authors investigate and analyze the reasons behind the variations in the techno-economic results generated from seven different techno-economic models which are commonly used for construction and operation of CO2 pipelines. Such variations often translate into tens or, at times, hundreds of millions of dollars in terms of initial financial estimates at the Pre-FEED (Front End Engineering Design) or FEED stages for Carbon Capture and Storage (CCS) projects. Variations of this magnitude can easily bring much unwanted uncertainty to the feasibility of a CO2 pipeline project and they can potentially cause a major over or under estimation of the project’s true costs. The summary of a detailed analysis and assessment for these seven existing techno-economic models for CO2 pipeline transport has been presented in this paper. The analysis conducted indicates that some of these models are essentially identical and are rooted in similar fluid mechanics theories and assumptions. This type of analysis assists with explaining and narrowing down the variability of the models’ results. Based on these analyses, a refined and more accurate model was established and the development process was explained. The refined model uses the Reynolds number, Colebrook-White equation using the Darcy friction factor, and the Darcy-Weisbach pressure drop equation to establish the most accurate measure for the pipe’s diameter. To assess the CO2 pipeline’s total capital cost, total annual cost, and the levelized transport cost, a statistical regression analysis approach was suggested and the adjusted-r2 measure was proposed to assess the goodness-of-the-fit of the generated cost function. The accuracy of the new techno-economic model was validated with the figures of a proposed CO2 infrastructure project in the United Kingdom and also through hydraulic modeling.
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Shi, Yushu, Sitian Gao, Xu Song, et al. "The assessment of industrial CT's probing error." In SPIE/COS Photonics Asia, edited by Sen Han, Toru Yoshizawa, and Song Zhang. SPIE, 2014. http://dx.doi.org/10.1117/12.2071795.

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Lanzini, Andrea, Thomas G. Kreutz, Emanuele Martelli, and Massimo Santarelli. "Techno-Economic Analysis of Integrated Gasification Fuel Cell Power Plants Capturing CO2." In ASME Turbo Expo 2012: Turbine Technical Conference and Exposition. American Society of Mechanical Engineers, 2012. http://dx.doi.org/10.1115/gt2012-69579.

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This work analyzes the efficiency and economic performance of different configurations of a coal-fed Integrated Gasification Fuel Cell (IGFC) plant with CO2 capture. Our analysis evaluates novel configurations, providing a detailed economic assessment for each case. The plants studied here are based on a pressurized Solid Oxide Fuel Cell (SOFC) based power cycle integrated with a Shell coal gasifier. The design variations focus on syngas cleaning and pre-processing upstream of the SOFC power island. In particular, we have designed, simulated and optimized three main system configurations; two with a partial methanation process upstream of the SOFC (‘TREMP’ and ‘HICOM’ cases, respectively) and one without (‘DIRECT’ case). Depending on the specific plant layout, carbon capture is accomplished either before or after the SOFC power island, or both. The best performance, both thermodynamic and economic, was achieved by the HICOM case, whose coal-to-electricity conversion efficiency is 50.6% (lower heating value basis). In addition to outperforming the other IGFC configurations analysed, compared to a conventional IGCC-CCS plant, the ‘HICOM’ case produced over 20% reduction in the levelized-cost-of-electricity (LCOE) delivered by the power plant.
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Yang, Xue, Gang Li, and Ling Lin. "Assessment of spatial information for hyperspectral imaging of lesion." In SPIE/COS Photonics Asia, edited by Qingming Luo, Xingde Li, Ying Gu, and Yuguo Tang. SPIE, 2016. http://dx.doi.org/10.1117/12.2245874.

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Reports on the topic "Cost Assessment of CCS"

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Demaestri, Edgardo C., Cynthia Moskovits, and Jimena Chiara. Management of Fiscal and Financial Risks Generated by PPPs: Conceptual Issues and Country Experiences. Inter-American Development Bank, 2018. http://dx.doi.org/10.18235/0001470.

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This paper discusses the main issues concerning sovereign fiscal and financial risks from public–private partnerships (PPPs) with a focus on contingent liabilities (CLs). It is based on the presentations and discussions that took place during the XI Annual Meeting of the Group of Latin American and the Caribbean Debt Management Specialists (LAC Debt Group), held in Barbados in August 2015. The main issues discussed include PPP risks assessment, institutional framework for PPP risk management, and accounting and reporting of CLs generated by PPPs. Six country cases (Chile, Colombia, Costa Rica, Honduras, Suriname, and Turkey) are presented to illustrate experiences with different degrees of development regarding the management of risks and CLs related to PPPs. The document concludes that PPP risk management should encompass the whole lifecycle of a PPP project, risks need to be identified and CLs must be estimated and monitored, and the institutional capacity of governments to evaluate and manage PPP risks plays a central role in the successful development of PPP contracts. Although institutional capacities in this regard have improved in recent years, estimations of CLs involved in PPPs are not regularly performed, and there is still room for improvement on the assessment, measurement, registration, budgeting, and reporting of risks and CLs related to PPPs.
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Kujawski, Edouard, and Diana Angelis. Dynamic Cost Risk Assessment for Controlling the Cost of Naval Vessels. Defense Technical Information Center, 2009. http://dx.doi.org/10.21236/ada512312.

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Sheffield, J., R. A. Dory, S. M. Cohn, et al. Cost assessment of a generic magnetic fusion reactor. Office of Scientific and Technical Information (OSTI), 1986. http://dx.doi.org/10.2172/6086979.

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Balut, Stephen J., and John J. Cloos. Assessment of the Contractor Cost Data Reporting (CCDR) System. Defense Technical Information Center, 1994. http://dx.doi.org/10.21236/ada285786.

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Tevis, J., J. Hirahara, B. Thomas, and M. Mendez. Lawrence Livermore National Security Cost Model Functional Management Assessment. Office of Scientific and Technical Information (OSTI), 2008. http://dx.doi.org/10.2172/945520.

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Hinkle, Wade P., Milton L. Tulkoff, and Rachel D. Dubin. References for Capability Assessment, Acquisition Planning, and Cost Estimation. Defense Technical Information Center, 2011. http://dx.doi.org/10.21236/ada552348.

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Yuracko, K. L. Assessment of Cost Savings of DOE's Return-on-Investment Program. Office of Scientific and Technical Information (OSTI), 2000. http://dx.doi.org/10.2172/885556.

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D. Lancaster. COST IMPACT OF ROD CONSOLIDATION ON THE VIABILITY ASSESSMENT DESIGN. Office of Scientific and Technical Information (OSTI), 1999. http://dx.doi.org/10.2172/862232.

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Yuracko, K. L., B. Tonn, and M. Morris. Assessment of cost savings of DOE's return-on-investment program. Office of Scientific and Technical Information (OSTI), 1999. http://dx.doi.org/10.2172/750986.

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Contini, Vince, Mike Heinrichs, Paul George, et al. Final Report - Stationary and Emerging Market Fuel Cell System Cost Assessment. Office of Scientific and Technical Information (OSTI), 2017. http://dx.doi.org/10.2172/1353409.

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