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Abstract: As one of the world''s top energy consumers and carbon emitters, China attracts extensive attention to its energy issues. Based on the hybrid energy input-output model, this paper forecasts the direct and indirect household energy demand growth caused by higher living standards in China with reference to a national well-off goal by 2020. Results show that such rigid energy demand will increase 1.55 billion tce by 2020 with average growth rate of 5.2% on static assumption, or 1.3 billion tce if energy conversion efficiency changes from 69% to 71.6%. If unchanged household energy consumption structure is assumed, total energy demand could decline from 5.5 billion tce to 4.9 billion tce by 2020. [Copyright &y& Elsevier]

Abstract: The “low-hanging fruits” (LHF) (or cream-skimming) problem receives some attention in recent years. However, few studies provide formal analysis on the LHF problem and other flaws based on economic theory. This paper investigates the LHF problem of Clean Development Mechanism (CDM) in China. The energy consumption and the Green House Gas (GHG) emission in China are outlined. The details of the CDM projects, including their distribution in China, and the types of projects are summarized. In order to test whether there were LHF problems in China, a simple statistical model is developed. The statistical analysis provides an indirect evidence that the LHF problem exists in China. The results indicate that areas with higher emission of GHG and low level of GDP per capita attract more CDM projects with higher amount of Certified Emission Reductions (CERs). The results are robust after eliminating HFC-23 decomposition projects from the sample. [Copyright &y& Elsevier]

Abstract: This paper takes Jiangsu province as an example, divides the zone of energy risks and uses GM (1, 1) and the combination of BP network model to forecast energy demand in this region.Finally, we adopt ARCEngine secondary development achieving the system simulation, and putting forward a strategic suggestion on energy problem of Jiangsu province. The study provides the scientific data support for making energy policy rationally, reducing the increasingly prominent phenomenon of energy demand and offer support for different levels in different departments. It can provide the scientific basis for risk prevention and comprehensive risk management plan. © 2011 Published by Elsevier Ltd. Selection and peer-review under responsibility of RIUDS [Copyright &y& Elsevier]

Abstract: taking energy consumption per ten thousand Yuan unit GDP as energy consumption quality indicator and using, this paper analyses the relationship between energy consumption quality and the level of education and technology of Jiangsu province based on grey relation theory. Conclusion shows that, according the importance order, the influence factors of Jiangsu energy consumption quality is as following: scientific and technological personnel, number of college students per ten thousand in number, number of R&D funds. Therefore,to improve the energy consumption quality, we should improve technology personnel level and education level.at the same time,we should enlarge fund investment. [Copyright &y& Elsevier]

Abstract: In recent years, the renewable energy such as wind energy or solar energy is well developed in China, but the green electricity generated from these sources is still difficult to operate commercially. To promote the development of green electricity market, this paper takes Jiangsu Province as examples and explores the consumption mode of green electricity. Through questionnaires design and investigation, we find that information dissermination, green value and bandwage effect play an important role in people''s subsriciption intention, while the actual purchase behavior is mainly drived by subsriciption intention, rather than payment capacity. It implies that we should strengthen the knowledge popular of green electricity through school education, media dissernmination and the spread of green knowledge in the community. © 2011 Published by Elsevier Ltd. Selection and peer-review under responsibility of RIUDS [Copyright &y& Elsevier]

Abstract: The global energy issues have stimulated increasing research interest in the linkages between the energy consumption and economic growth. As the biggest developing country, China has surpassed United States to be the world''s largest energy consumption country. This paper examines the casuality between GDP and energy consumption by using updated China provincial panel data for the period 1985–2007 within a multivariate framework by adopting Pedroni''s panel methodology. The results show that cointegration is present between real GDP, energy consumption, the labor force, and real gross fixed capital. The results of Granger-causality test indicate the presence of Bi-directional causality between energy consumption and economic growth which supports the feed back hypothesis.Economic interpretations of the empirical results are also presented. [Copyright &y& Elsevier]

Abstract: The relationship between energy consumption and economic growth has long been the focus at home and abroad. The general view is: energy consumption promotes economic growth; economic growth affects energy consumption on the other hand. In sight of the original theory, this paper adopts the statistical data of Shandong Province from 1980 to 2008, which include Gross Domestic Products (GDP), energy consumption, fixed asset investment and employees. Using unit root, co-integration and Granger causality test, we examined the relationship between energy consumption and economic growth in Shandong Province. The results show that energy consumption and economic growth have long-term trend relation, and there is two-way causality between them. The econometric model is estimated using Generalized Least Square (GLS) method. The conclusions are as follows: energy consumption and economic growth is positively correlated in Shandong province, and economic growth has highly depended on energy consumption. [Copyright &y& Elsevier]

Abstract: According to the industry ecology theory, in the simulating flowing way between substance and energy in the nature ecology, to design the industrial production systems can use less resource reasonably and reduce emissions. As the most important large iron & steel enterprise in Inner Mongolia, applying the theory of industrial ecology, the Baogang Group gains great achievement in energy saving and emission reduction in recent years. Based on the industrial ecology theory, this paper mainly analyzes the practice of energy-saving and ejection-decreasing of the BaoGang Group. [Copyright &y& Elsevier]

Abstract: Energy-saving and emission-reduction are the major challenge to the development of countries in the world. When it comes to China, it refers to properly handle the regional issues. According to the common trends of the average industrial SO2 emission per square kilometer in three developed regions (Yangtze River Delta, Pearl River Delta and Bohai Economic Circle) and the remaining regions in the east, the middle and the west, this paper conducts an empirical analysis on the issue of pollution emission spilled from the developed regions to the remaining provinces. The result shows that the pollution emission in developed regions significantly demonstrates the role-model effect to the remaining provinces, and the effect will be weaken as the distance from the remaining provinces to three developed regions increases, which somewhat interprets the common trend of pollution emission among regions. Meanwhile, the role-model effect gives us the policy recommendation that China shall pay full attention to the exemplary role played by the developed regions on the issue of energy-saving and emission-reduction. [Copyright &y& Elsevier]

Abstract: This paper describes an investigation for multi-stage systems used in coal-fired power plant. The whole work was divided into two steps: energetic and economic analyses. In the first step: on the basis of a serial concept, through varying the position of compressors and vacuum pumps, recycling the retentate of the 2nd membrane to the feed side of the 1st membrane, a cascade variant was developed and analysed. In the second step: an economic model was developed to calculate the capture cost of the cascade system. The total cost is composed of investment cost, operation and maintenance (O&M) cost and electricity cost. A correlation between the membrane parameters: selectivity & permeability and capture performance: energy consumption & capture cost was built up. Using Polyactive® membrane developed by GKSS with CO2 permeance of 3 Nm3/m2hbar and CO2/N2 selectivity of 50, under the separation target of 70% degree of CO2 separation and 95 mol% CO2 purity, adopting the cascade membrane system in the 600 MW NRW-reference power plant, the specific energy consumption including CO2 compression (110 bar, 30 °C) is 256 kWh/tseparatedCO2 with 6.4%-pts efficiency loss. The capture cost is 31 euro/tseparatedCO2 , which could be a promising solution as a retrofit for the existing power plants. [Copyright &y& Elsevier]

Abstract: An energy network with polygeneration system and CCS suitable for China was proposed in our previous work in consideration of low-cost CCS and energy providing safety. In this paper, based on life-cycle analysis, the role of the Energy Network has been investigated at the national level. Results show that with the import dependency of oil controlled in the range of 40%–60% during 2020 to 2030, up to 22% of the total capacity of coal fired supercritical power plants may be replaced by hundreds of new polygeneration plants for electricity and alternative fuels. When the oil import dependency will be kept from 40% to 60%, the Energy Network can save 20%–30% of energy and cut down 30%–40% of total costs every year compared to the present method with coal fired supercritical power plants and traditional alternative fuel plants with CO2 capture. And the Energy Network can capture more than 0.1 billion tons of CO2 with high concentration over 98% each year. Moreover, from the aspect of CCS, this Energy Network can realize as low as 15$/t of total CCS cost due to the quite low energy penalties of CO2 capture in the polygeneration systems and the combination of CO2 sources and storage sites. The new Energy Network has realized the proper combination of energy utilization and CO2 capture and storage according to the unique state of China. It is suitable for China and may play an important role in CCS in the future. [Copyright &y& Elsevier]

Abstract: Energy sources such as oil, natural gas, and coal currently account for around 80% of the world’s primary energy consumption. Despite significant investments in renewable energy and energy efficiency, that Canada and others are making, the International Energy Agency (IEA) has forecast that as the global economy continues to grow, fossil fuels will continue to dominate the world’s energy supply for decades. Reconciling the world’s ongoing reliance on fossil fuels with the need to reduce greenhouse gas (GHG) emissions is then one of our greatest challenges. Canada is taking this challenge seriously with climate change policies that include enhancing our global leadership in advancing one of the most promising technologies for reducing GHG emissions from fossil fuel use: Carbon capture and storage (CCS). CCS is only one of several technologies that must be deployed and is not a ‘silver-bullet’ for meeting Canada’s target of reducing its GHG emissions by 17% from 2005 levels by 2020. Yet, CCS is one of the only technologies currently available for making emissions reductions from large-scale fossil fuel usage–and, thus, will be a critical component of the technology puzzle for Canada to meet its emissions reduction objectives. Canada has a number of key sectors where the deployment of CCS is needed and there are opportunities to advance the technology. These include coal-fired electricity plants, the oil sands, and natural gas processing (e.g. from the new development of shale gas) -though the opportunity and demand for advancing CCS technology also exists in other sectors such as chemicals, fertilizer, steel making, and cement. Federal and provincial governments in Canada are making substantial investments in CCS, committing upwards of $3 billion in public funding towards seven large-scale fully-integrated CCS demonstration projects. The federal ecoENERGY Technology Initiative announced $151 million for the initial engineering and/or pilot stages of seven potential demonstration projects in 2008. The 2009 federal budget created Clean Energy Fund, which included $610 million for CCS demonstrations. The Provinces of Alberta, Saskatchewan, and British Columbia have also committed funding for demonstrations, in particular $2 billion by Alberta. This public funding will leverage additional investment from industry, for projects that will each capture and store on the order of 1 million tonnes of CO2 per year, coming on-line starting in 2015 or sooner. This paper will provide an overview of Canada’s actions on advancing CCS deployment, with a focus on the CCS demonstration program and current R&D activities in Canada. [Copyright &y& Elsevier]

Abstract: The oxy-fuel combustion CO2 capture route and post-combustion CO2 capture route involve different energy consumption rates and subsequent environmental impacts. The holistic perspective offered by Life Cycle Assessment (LCA) can help decision makers to compare alternative CO2 capture and storage technologies in a life cycle perspective. This paper, at first, introduces the principles of the dynamic LCA model developed for oxy-fuel combustion and post-combustion power generation with CO2 capture, transport and injection processes. Next, a comparative life cycle assessment of alternative CO2 capture technologies is presented. Results show that, at life-cycle level, the post-combustion and oxy-fuel combustion CCS cases can reduce the life-cycle Global Warming Potential (GWP) by 78.8% and 80.0% respectively compared to conventional power plant without CCS. Other environmental impacts, such as Ecotoxicity, Human toxicity and Acidification, vary significantly with the different CO2 capture routes employed. Finally, by comparing the results obtained with the most recent LCA studies of post-combustion power generation with CO2 capture and storage, it is shown that the plant level, gate-to-gate studies provide significantly variable results and generally overestimate life cycle environmental impacts. [Copyright &y& Elsevier]

Abstract: This paper presents the results of careful considerations on the surface facilities at one of the most promising CCS (Carbon dioxide Capture and Storage) candidate sites in Japan in regards to process, economy and energy consumption. This site has been selected to demonstrate the feasibility of CCS total system in which CO2 is captured from natural gas processing plants, transported to the injection site (100 km away from the plants), and then stored in the saline aquifers underneath the seabed of the Japan Sea. Four technical issues have been reviewed for the surface facilities, namely CO2 transportation, removal of impurities in the CO2 gas, the liquefied CO2 heater models and the shaft seal system for CO2 pumps. As for the CO2 transportation method, tanker trucks transportation is selected compared to pipelines because of the merits in a construction period, economy, and local citizen’s understanding and acceptance which are crucial for the realization of the project. Concerning process building, removal of impurities contained in the CO2 gas has been considered first. CO2 gas separated from natural gas contains hydrogen sulfide, mercury, and BTX in addition to water. These impurities must be eliminated prior to liquefaction of CO2 because they could interfere with the process as well as for environmental considerations. The adsorption method is found to be effective for removing all these impurities. However, it is also found that adsorbent consumption rate depends largely on the process sequence with which the impurities are eliminated. After reviewing the results, it is found that the most economical sequence to eliminate these impurities is in the order of mercury, hydrogen sulfide, BTX, then water. Liquefied CO2 heater models have been considered to reduce CO2 emission. After transportation to the injection site, the liquefied CO2 is pressurized and heated from −10 °C to a super critical state of 40 °C in order to avoid phase transition inside the injection tube. Using a heat pump to utilize the heat in the air to improve the energy efficiency, CO2 emission is substantially reduced by approximately 70% compared to the conventional method using hot water from a boiler that uses heavy fuel oil. A centrifugal pump will be selected for CO2 pumps because it can handle large volumes. An effective shaft seal system is the tandem formation using vapor-liquid seal and dry gas seal for the first and the second stages respectively. However, since we have limited experience of this formation at CO2 pumps in Japan, it is identified as a critical item in the demonstration project. [Copyright &y& Elsevier]

Abstract: To fulfill the energy demand now and in the next decades, coal-fired power plants will be an essential part of the portfolio of power plants that supply electricity cheaply and in a reliable way. The specific CO2 emissions of these plants can be reduced by increasing the efficiency. For that reason KEMA did optimize the steam water cycle of ultra super critical (USC) coal-fired power plants within the EOS program. The improvements are based on the application of the so-called Master Cycle, and on the application of higher steam temperatures. In the Master Cycle cold reheat steam is used in an extra turbine and with steam extraction of this turbine feed water preheating is realized with reduced exergy losses. The turbine is called a tuning turbine reflecting the improved possibilities to tune and optimize the steam cycle with the new coupling where the regenerative heater train and the re-heaters have been decoupled. The Master Cycle is proposed by Dong Energy . The first approach deals with the USC technology with a steam temperature of 600 °C and reheat temperatures of 620 °C. This technology is available at the moment and is applied in new built coal-fired power plants. The second approach deals with the USC technology with a steam temperature of 700 °C and reheat temperature of 720 °C. The expectation is that this technology can be applied around 2025 with the same availability as the USC units with 600 °C. The thermodynamic analyzes are carried out with KEMA’s flow sheeting package SPENCE®. In all considered cases the thermal input was 2400 MWth. In case of the application of the Master Cycle a second reheat is introduced. Results will be discussed and presented in tables, t-s diagrams and h-p diagrams. Improvement of efficiency of coal fired power station technology can reduce the amount of CO2 emitted significantly. This paper shows that with current available technology and improvements an additional emission reduction of almost 10% can be realised by applying the USC 700 + MC. Compared to the world wide average an emission reduction of 66% can be achieved without CCS. In the continuation of the analysis post combustion technology will be integrated in the concept to analyze possible additional benefits of the master cycle with respect to steam supply for the regeneration of the solvents. [Copyright &y& Elsevier]

Abstract: This paper explores the resource intensity and major cost elements of direct air capture of carbon dioxide. The levelized cost of carbon removal is calculated as the sum of costs resulting from interdependent capture devices, energy supplies, water supplies and sequestration resources. The analysis considers “generic” air capture technology characterized only by its energy use, capture footprint, and water use. Capital costs dominate the analysis, followed by energy efficiency. Four dedicated energy resources are considered: Wind, enhanced geothermal, natural gas combined cycle (NGCC), and NGCC with 90% carbon capture. Nearly carbon-free energy is critical to keeping overall cost of carbon mitigation low. The analysis shows that high second law capture efficiencies (on the order of 10%) and relatively inexpensive capture devices (on the order $0.5 M for an individual device capturing one tonne CO2/day) must be achieved if the cost of air capture is to approach $300/tonne- CO2. Reaching those goals is likely to require substantial research into the kinetics and thermodynamics of capture chemistry which, respectively, keep the capital and energy costs as low as possible. [Copyright &y& Elsevier]

Abstract: To make the deployment of carbon capture possible, it is highly needed to develop original solutions that induce low energy penalty and that are easy to operate. This paper aims at presenting the DMX™ process developed at IFP Energies nouvelles based on special solvents which are characterized by the formation of two immiscible phases for given temperature and CO2 loading conditions. The concept of demixtion is briefly described in terms of physico-chemical properties, its interest and all required steps for appropriate process development are discussed. The corresponding process is presented and a technico-economic analysis is given. It is shown than one can reach a reboiler duty as low as 2.1 GJ/t CO2 which is significantly lower than the 3.7 GJ/t CO2 of the 30wt.% MEA reference process. It is also discussed that the energy consumption at reboiler cannot be the only parameter to consider for comparison with other processes and some further information about the DMX™ process are given. Operational issues are particularly discussed. In that sense, the performances of the DMX-1TM solvent in terms of degradation and corrosion are shown. Similarly a particular focus is made on the liquid/liquid separation which is a key aspect of the DMX™ process. [Copyright &y& Elsevier]

Abstract: TOTAL Exploration and Production is involved in a number of production and/or processing projects such as Heavy oil, Oil sands and LNG which require substantial amounts of energy (heat and power). Alongside this, sustainable development of energy resources is a prime target for the Total group, which strives constantly to reduce the GHG intensity of its production activities. On new projects and for major plant modifications, this is achieved by optimizing energy efficiency and preventing continuous flaring of produced gas, which is marketed or re-injected instead. On current producing installations, a continuous improvement process to address flaring reduction and energy efficiency is on-going. However in view of the coming development challenges, Total is further considering the development of facilities with a limited GHG footprint, by the means of emissions reduction through carbon capture and sequestration. Designing capture-ready installations is the first step on this path. It is a challenging task owing to the evolving nature of available technology, the high energy demand and correlative emissions of carbon and the unusual specific constraints in dedicated Oil and Gas energy plants. This paper presents our experience in this learning process applied to the oil & gas industrial environment. With the collaboration of Technip, Total initiated a study on the integration of carbon-capture solutions within cogeneration plants. On the strength of its in-house experience of oxy-combustion and acid gas removal, of transport and re-injection of acid gases, Total considered both oxy-combustion and post-combustion as promising technologies. The objective of the study was to assess the potential of each technology to tackle carbon capture on the two main types of thermo-mechanic converters present in a cogeneration plant: turbines and boilers, as well as evaluate the constraints. Alternative cogeneration plant concepts, with or without combined cycle were considered, to challenge further the impact of capture on cogeneration design. The actual operating conditions of a typical cogeneration plant burning clean natural gas, particularly its flue gas emissions, compatible with the target project’s constraints, were proposed as the design basis for capture systems of various scales. The requirement to keep to simple capture concepts was critical in view of the challenging economic environment of carbon capture, the evolving technology and the probable tightening of emission-reduction targets. Due to the uncertainties as to the final fate of the carbon dioxide, EOR or/and geo-storage, nearby or distant, in depleted fields or saline aquifers, being considered, several CO2 conditioning process options were defined. The integration of capture-ready building blocks within the plants was a significant step in the design process for alternative cogeneration plants, and enabled the synergies and constraints of operating the capture systems to be identified. The key risk items were highlighted, offering insight into the expected roadmap of the capture technology development. The results of this work compare the main features of the oxy-combustion and post-combustion CO2 capture technologies for steam-boiler and/or gas-turbine effluents and flag up some essential local constraints affecting the performance of the various capture-ready cogeneration schemes. [Copyright &y& Elsevier]

Abstract: This paper presents the methodology and the preliminary results of a techno-economic assessment of CCS implementation on the iron and steel sector. The results show that for the short-mid term, a CO2 avoidance cost of less than 50 € /tonne at a CO2 avoidance rate of around 50% are possible by converting the conventional blast furnace (BF) to Top Gas Recycling Blast Furnace (TGRBF). However, large additional power consumption for CO2 removal and oxygen generation, and reduction in BF gas export, makes the economic performance of the technology very sensitive to energy prices. Add-on CO2 capture for conventional BF may achieve similar costs (40–50 € /t CO2 avoided), but the CO2 avoidance rate will be only about 15% of the specific CO2 emissions. For the long term future, although there are large uncertainties, advanced CO2 capture technologies do not seem to have significant economic advantages over conventional technologies. The results also indicate that in a carbon-constrained society, when considering new plants, smelting reduction technologies such as the COREX process, may become a strong competitor to conventional blast furnace based steel making process when equipped with CO2 capture. Although conventional iron and steel making using BF is expected to dominate the market in the long term, strong need for drastic CO2 emissions reduction may drive the sector towards large scale implementation of advanced smelting reduction technologies. [Copyright &y& Elsevier]

Abstract: The California Global Warming Solutions Act of 2006 sets a goal for the state to reduce its greenhouse gas emissions to 1990 levels by 2020. In preparation for implementation of a cap and trade program under this Act, Chevron has undertaken a detailed assessment of greenhouse gas mitigation options and costs. Such an assessment is key to making compliance decisions within the constraints of a given cap and trade regime. If the cap and trade market is minimally restricted (i.e., recognizes that climate change is a global issue and thus has no geographic restrictions and no set requirement for onsite emission reductions), facilities can make the best economic (and environmental) choices of where to ‘make’ emission reductions inside the facility fenceline and when to ‘buy’ the emission reduction allowances or credits on the market. The scope of the study included Chevron’s two refineries and a large heavy oil steamflood production operation in California. This paper will discuss how mitigation technologies are identified and assessed, describe some of the key greenhouse gas mitigation alternatives of interest to the Chevron California facilities and present a business-based approach to analyzing mitigation costs. Technologies studied included energy efficiency, advanced energy (solar, wind, geothermal, biomass, nuclear, low temperature heat recovery) and carbon dioxide capture and storage (CCS). For each mitigation option, a consistent methodology, based on the International Petroleum Industry Environmental Conservation Association/American Petroleum Institute (IPIECA/API) Guidelines for Evaluation of Greenhouse Gas Emission Reduction Projects was used to assess baseline or ‘business as usual’ emissions, net emission reductions due to the project, capital cost, operating cost and any project benefits (e.g., reduced fuel use for energy efficiency projects). These values were then entered into a business evaluation tool to calculate a Net Present Value for each option. Key conclusions: [•] Broad involvement of various disciplines is needed to identify new alternatives for greenhouse gas mitigation technologies. [•] Other than CCS, options for significant reductions of refinery and petroleum production emissions were extremely limited in the facilities studied. [•] Since cost-effective, feasible options are limited for refineries and petroleum production facilities, availability of sufficient allowances and offsets is an important element if state goals are to be achieved. [•] Although a number of energy efficiency projects were identified, the cumulative total emissions reductions available through energy efficiency projects is minimal. [•] Renewable and advanced energy projects that generate electricity generally have very high mitigation costs, and may not greatly benefit facilities if emission caps apply only to direct emissions, since these projects reduce the quantity of purchased electricity rather than emissions from the facility itself (and are therefore not eligible for credit under most regulatory design schemes). [•] Renewable and advanced energy technologies for steam generation may have significant mitigation potential for heavy oil steamflood production. Further development and demonstration is needed to determine whether these technologies will be viable. [•] In order to support good business decisions, it is important that greenhouse gas mitigation technology evaluation be done in a manner consistent with other business evaluation processes. [Copyright &y& Elsevier]

Abstract: For most CCS projects, captured CO2 is transported by pipeline, in contrast to shipping it, which has only been introduced as a secondary option for long distances and small amounts. This paper provides some possible alternatives to reduce the total cost of CCS through CO2 shipping. The benefits of HP pump in power consumption is considered and a new total CCS chain is suggested, which can be divided into capture, liquefaction (or compression to supercritical fluid), transport by ship, compression by HP pump, and storage. With a highly efficient liquefaction process, CO2 shipping costs can be reduced under a new total CCS chain. The results of our study show that an optimal size needs to be adopted for each CCS project, enabling CO2 shipping to be more cost efficient. DSME has developed a concept design for a large CO2 carrier that has the potential to be more cost-effective than conventional transport. Therefore, CO2 transport by ship should now be seriously re-considered as an effective transport method on a project-by-project basis. [Copyright &y& Elsevier]

Abstract: This paper presents an environmental assessment of three scenarios postulating a national deployment of the Carbon Capture and Storage (CCS) chain by 2020–2050 on the French biggest industrial CO2 emitters (41 emitters among 9 industrial sectors) that had been carried out as part of the SOCECO2 project. 1 [1] SOCECO2 project, funded by the French National Research Agency, 2006–2009, involving the following partners: ALSTOM Power, APESA, BRGM, CNRS-CIRED, GDF Suez, IFP Energies nouvelles, INERIS, TOTAL. This analysis is based on the comparison of these CCS scenarios with reference scenarios without CCS at the same timeframe. Results detailed below focus on greenhouse gas (GHG) emissions and energy consumption, although NOx and SOx emissions balances have also been evaluated in the same project. Conclusions of this study provide information about the extent and main contributing factors of potential environmental outcomes (negative or positive) associated to CCS deployment. [Copyright &y& Elsevier]

Abstract: This paper presents an overview of some recent CO2 storage capacity assessments in the Songliao and Subei Basins in China, and a discussion of some of the specific challenges that must be addressed to further assess the feasibility of CO2 storage in China. Geological CO2 storage associated with CO2-EOR is of significant interest in these basins as it offers potential to increase oil production and provide additional fuel to meet China’s increasing energy consumption. Although some CO2 is stored during such flooding projects, the greatest storage potential is only realised at the end of a field’s productive life, when a depleted field can be used as a dedicated CO2 storage reservoir. The Songliao Basin, in North-eastern China has been the largest oil and gas producing province in China. The oilfields of the Daqing and Jilin oil provinces are estimated to have effective CO2 storage capacities of 593 Mt and 71.2 Mt respectively. Extrapolation of data from around the oilfields to the whole basin suggests that the most promising saline aquifer in the basin has a theoretical storage capacity of 692 Mt CO2: Its effective storage capacity (which cannot be estimated due to lack of data) is likely to be considerably smaller however. Limited data availability means the estimate of storage capacity in this saline aquifer is based on gross simplifications and extrapolation across large areas (e.g. basin-scale) but could provide a basis for comparison with the potential for CO2 storage in other regions in China, or to help prioritise more detailed analysis. Although smaller, the onshore oilfields of the Subei-Yellow Sea Basin were also assessed, as the presence of mature oil and gas fields and natural CO2 accumulations, suggest suitable targets for storage may be found. The total effective storage capacity of the 108 hydrocarbon fields in this basin are estimated to be only 21 Mt CO2. While small, these fields may offer niche storage options for smaller industrial CO2 sources, but if CCS is to contribute to reducing China’s growing CO2 emissions, then further evaluation and development of storage in saline aquifers is likely to be needed at the same time as storage in oil or gas fields. [Copyright &y& Elsevier]

Abstract: The Energy Sector is facing its biggest upheaval. Governments around the globe are discussing the best way to combat climate change. Different mechanisms and policies have been introduced to reach a global carbon dioxide reduction of up to 80% by 2050, based on 1990 emission levels. The difficulties in applying different instruments at the same time are often not considered in the discussion of different instruments. However to achieve an effective and efficient reduction of emissions, a look at the whole bundle of instruments and their interrelationship is necessary when future regulations are discussed. This paper will critically assess the effects and the interrelationship of ETS, EPS and feed in tariffs from a European perspective. [Copyright &y& Elsevier]

Abstract: China’s economy has been on a solid fast growth track since 1978. The economy expanded by an average annual rate of about 10% during the last thirty years. That is more than triple the average growth rate of the world economy during the same period. The rapid economic development has been associated with growing energy consumption and carbon dioxide (CO2) emission. Although the first phase of the Kyoto Protocol exempts China from reducing its own CO2 output, China, as the first or second largest CO2 emission country, is facing growing international political pressure. As a responsible big country, China will almost certainly have to respond to climate change in the future. China is entering unexpected fast development period of the industrialization, urbanization and motorization, in which large-scale new infrastructures will be built. This provides great opportunity to plan for longer-term CO2 mitigation—the infrastructures built today have a long life time and are not easy to upgrade the technologies involved, and decisions made now will have a major impact on energy utilization mode and CO2 mitigation technology option in coming years. Carbon Capture and Storage (CCS), as an option in the portfolio of mitigation actions to combat climate change, is expected to have far-reaching implications for China. This paper (1) explores the strategic significance of CCS for China by making an extreme scenario analysis of Chinese power sector in 2030; (2) provides an overview of the recent CCS activities in China; and (3) identifies the major challenges with respect to CCS development in China and put forwards immediate strategies. [Copyright &y& Elsevier]

Abstract: The European DYNAMIS project is part of the HYPOGEN quick-start programme and aims at investigating viable routes for large-scale cost-effective combined hydrogen and electricity production with integrated CO2 Capture and geological Storage. This paper presents the environmental evaluation carried out for each technology option studied, producing Hydrogen and Electricity with CCS. The methodology used is based on Life Cycle Analysis (LCA) principles and concentrates on the assessment of two criteria: GHG emissions and non renewable primary energy consumption. As with other evaluations performed in DYNAMIS (mainly focused on technical and economic aspects), these results lead to the selection of best concepts in terms of environmental efficiency by comparing and weighing up positive and negative effects (i.e GHG emissions reduction and increase of non-renewable primary energy consumption). [Copyright &y& Elsevier]

Abstract: This paper describes a detailed process optimization of the mass and energy balances for multi-stage membrane systems used in coal-fired power plants. Based on the recovery rate of 50% or 90% CO2 with 95 mol% CO2 purity, different concepts using recirculation of flue gas and variation of feed gas compressor and vacuum pump on the permeate side were developed and optimized to obtain minimum energy consumption. Simultaneously, a cost model was developed to make a further analysis of the optimized concept in view of the tradeoff balance between material and energy consumption. [Copyright &y& Elsevier]