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In this paper an approach for analysing the potential for implementation of different technology pathways for the European pulp and paper industry (PPI) is presented. The approach is based on detailed technical research and aggregates the knowledge from previous studies to incorporate the whole European PPI. Thus, the potential for different technology pathways can be estimated on a European level whilst still considering important characteristics of individual mills. The usefulness of the approach was exemplified by applying it to a case study of the potential for introduction of carbon capture and storage (CCS) within the European PPI. The results from the case study show that for the European PPI, CCS has an up-hill road in order to be a viable, large scale alternative for reduction of CO2 emissions. If CCS is to be introduced in large scale within the European PPI, large biomass-based point sources of CO2 emissions need to be included when planning for CCS infrastructure and also the infrastructure needs to be built out for clusters emitting <20 MtCO2/yr. [ABSTRACT FROM AUTHOR]

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Among a comprehensive scope of mitigation measures for climate change, CO capture and sequestration (CCS) plays a potentially significant role in industrialised countries. In this paper, we develop an analytical real options model that values the choice between two emissions-reduction technologies available to a coal-fired power plant. Specifically, the plant owner may decide to invest in either full CCS (FCCS) or partial CCS (PCCS) retrofits given uncertain electricity, CO, and coal prices. We first assess the opportunity to upgrade to each technology independently by determining the option value of installing a CCS unit as a function of CO and fuel prices. Next, we value the option of investing in either FCCS or PCCS technology. If the volatilities of the prices are low enough, then the investment region is dichotomous, which implies that for a given fuel price, retrofitting to the FCCS (PCCS) technology is optimal if the CO price increases (decreases) sufficiently. The numerical examples provided in this paper using current market data suggest that neither retrofit is optimal immediately. Finally, we observe that the optimal stopping boundaries are highly sensitive to CO price volatility. [ABSTRACT FROM AUTHOR]

Carbon dioxide capture and storage (CCS) links together technologies that separate carbon dioxide (CO2) from fixed point source emissions and transport it by pipeline to geologic reservoirs into which it is injected underground for long-term containment. Previously, models have been developed to minimize the cost of a CCS infrastructure network that captures a given amount of CO2. The CCS process can be costly, however, and large-scale implementation by industry will require government regulations and economic incentives. The incentives can price CO2 emissions through a tax or a cap-and-trade system. This paper extends the earlier mixed-integer linear programming model to endogenously determine the optimal quantity of CO2 to capture and optimize the various components of a CCS infrastructure network, given the price per tonne to emit CO2 into the atmosphere. The spatial decision support system first generates a candidate pipeline network and then minimizes the total cost of capturing, transporting, storing, or emitting CO2. To illustrate how the new model based on CO2 prices works, it is applied to a case study of CO2 sources, reservoirs, and candidate pipeline links and diameters in California. [ABSTRACT FROM AUTHOR]

This paper takes the 'policy failure' in establishing a global carbon price for efficient emissions reduction as a starting point and analyzes to what extent technology policies can be a reasonable second-best approach. From a supply-side perspective, carbon capture and storage (CCS) policies differ substantially from renewable energy policies: they increase fossil resource demand and simultaneously lower emissions. We analyze CCS and renewable energy policies in a numerical dynamic general equilibrium model for settings of imperfect or missing carbon prices. We find that in contrast to renewable energy policies, CCS policies are not always capable of reducing emissions in the long run. If feasible, CCS policies can carry lower social costs compared to renewable energy policies, in particular when second-best policies are only employed temporally. In case fossil resources are abundant and renewable energy costs low, renewable energy policies perform better. Our results indicate that a pure CCS policy or a pure renewable energy policy carry their own specific risks of missing the environmental target. A smart combination of both, however, can be a robust and low-cost temporary second-best policy. [ABSTRACT FROM AUTHOR]

In this paper, we develop a model to analyze the economics of carbon capture, transport, and storage (CCTS) in the wake of expected rising CO prices. We present a scalable mixed integer, multiperiod, welfare-optimizing network model for Europe, called CCTS-Mod. The model incorporates endogenous decisions on carbon capture, pipeline and storage investments, as well as capture, flow and injection quantities based on given costs, CO prices, storage capacities, and point source emissions. Given full information about future costs of CCTS-technology, and CO prices, the model determines a cost minimizing strategy on whether to purchase CO certificates, or to abate the CO through investments into a CCTS-chain on a site by site basis. We apply the model to analyze different scenarios for the deployment of CCTS in Europe, e.g., under high and low CO prices, respectively. We find that beyond CO prices of €50 per t, CCTS can contribute to the decarbonization of Europe's industry sectors, as long as one assumes sufficient storage capacities (onshore and/or offshore). We find that CCTS is only viable for the power sector if the CO certificate price exceeds €75 per t. [ABSTRACT FROM AUTHOR]

Mineralna karbonatyzacja jest jedną z metod ograniczania antropogenicznej emisji CO2. Metoda ta polega na wykorzystaniu naturalnego zjawiska wiązania ditlenku wêgla przez surowce naturalne lub beton. Od pojawienia siê w 1990 r. w NATURE pierwszej publikacji dotyczącej mineralnej sekwestracji CO2, prowadzone są badania nad wykorzystaniem zjawiska wiązania ditlenku wêgla. W wyniku procesu ditlenek wêgla wiązany jest w stałej formie, co powoduje, że metoda ta jest bezpieczna ekologicznie. Dodatkowo w wyniku reakcji, która jest egzotermiczna, uwalnia siê ciepło, które może byæ potencjalnie wykorzystane. Proces ten może byæ stosowany jako ostatni etap tech-nologii CCS (Carbon Capture and Storage). Mineralna karbonatyzacja może byæ realizowana jako metoda in-situ i ex-situ. Mineralna sekwestracja proponowana jest i badana zarówno dla surowców mineralnych, jak i odpadów. W Polsce szczególnie interesującą opcją jest zastosowanie do wiązania CO2 na drodze mineralnej karbonatyzacji odpadów energetycznych o wysokiej zawartości CaO i ograniczonym wykorzystaniu gospodarczym. Do wiązania CO2 przeanalizowano oprócz odpadów energetycznych również żużle hutnicze i pyły z pieców cementowych. Drugą opcją prowadzenia mineralnej karbonatyzacji jest stosowanie surowców naturalnych. Do mineralnej sekwestracji CO2 mogąbyæ potencjalnie stosowane minerały, takie jak: oliwin, serpentyn czy talk. W artykule przed-stawiono możliwości zastosowania surowców mineralnych do obniżenia emisji ditlenku wêgla. Przeanalizowano również surowce mineralne wystêpując w Polsce, które potencjalnie mogą byæ stosowane do sekwestracji CO2 w ramach procesu ex situ i in situ. Artykuł jest wstêpną analizą możliwości wykorzystania tego typu surowców do wiązania CO2 w Polsce. Mineral carbonation is one possible approach to reducing anthropogenic CO2 emissions. This method involves the use of a natural phenomenon of carbon dioxide causing CO2 to bond with natural or concrete materials. Since the appearance of the first publication on the mineral sequestration of CO2 (in 1990 in Nature), research has been conducted into making use of the carbon dioxide bond. The objective was to bind carbon dioxide into a solid form, a method rendering it environmentally safe. In addition, as a result of the reaction being exothermic, heat is released which can potentially be used. This process may be employed as the last step of CCS (Carbon Capture and Storage). Mineral carbonation can be implemented as a method both in situ and ex situ. Mineral sequestration is proposed and has been tested for both minerals and waste. In Poland, a particularly interesting option is the binding of CO2 through mineral carbonation of energy waste with a high content of CaO and limited economic use. Binding of CO2 has also been analyzed with use of the metallurgical slag and dust from cement kilns. Another option for mineral carbonation is the use of natural raw materials. To bind CO2 through mineral carbonation, minerals such as olivine, serpentine, and talc can be applied. This paper is a preliminary analysis presenting the possibility of using mineral raw materials to reduce carbon dioxide emissions. It also analyzes minerals occurring in Poland which can potentially be used to sequester CO2 in ex situ and in situ processes. [ABSTRACT FROM AUTHOR]

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

Abstract: The IEA CCS Roadmap highlighted the significance that CCS will play in achieving an atmospheric CO2 stabilization on 450 ppm. In the scenario it is based on, CCS will provide approximately 20% of the total CO2 emissions reductions out to 2050. To achieve this contribution it will require an ambitious CCS growth path with 100 projects needed globally by 2020 and over 3000 by 2050. In both 2020 and 2050 the major developing countries will need to contribute to this deployment. Brazil has a unique electricity and emissions profile. Over 80% of Brazils electricity is produced from hydropower with the rest being made up by a combination of fossil fuels, biomass, and nuclear. This means the energy emissions in Brazil are relatively low. Many people within Brazil see stopping the deforestation of the Amazon as the key emissions reduction mechanism for Brazil. However, the contribution to CO2 emissions from coal is expected to increase due to 6000 MW of coal power that is planned to be installed in Brazil by 2030, although this still only represents 2.7% of grid compared to 83% from renewables. CCS in Brazil will be more relevant to industry rather than for electricity generation. In particular CCS could be crucial for the development of some of the “Pre-salt” petrol eum fields which bring new challenges. Although there are no conclusive studies on the concentration o f carbon dioxide (CO2) in the region, some wells have shown concentrations of CO2 above those found in the Campos Basin, while others showed concentrations close to zero. Still, Petrobras have proactively committed to not releasing to the atmosphere, the CO2 associated with the natural gas produced in the pre-salt layer. In addition, the pre-salt oil is considered of good quality, light oil and therefore, the refining process consumes less energy and will emit less CO2 when compared to the processing of heavier crude. This paper looks to discuss the current status of CCS in Brazil. This includes looking at the current status of a number of demonstration projects that are already underway in Brazil as well as additional ones that are planned. The paper will also discuss the. Public awareness and engagement about CCS given the crucial role the public play in the smooth progress of projects. [Copyright &y& Elsevier]

Abstract: This paper estimates the cost of CO2 capture for three Australian industrial emission sources: iron and steel production, oil refineries and cement manufacturing. It also compares the estimated capture costs with those of post-combustion capture from a pulverised black coal power plant. The cost of capture in 2008 using MEA solvent absorption technology ranges from less than A$60 per tonne CO2 avoided for the iron and steel production to over A$70 per tonne CO2 avoided for cement manufacture and over A$100 per tonne CO2 avoided for oil refineries. The costs of capture for the iron and steel and cement industries are comparable to or less than that for post-combustion capture from a pulverised black coal power plant. This paper also investigates costs for converting low partial pressure CO2 streams from iron and steel production to a more concentrated stream using pressurisation and the water-gas shift reaction. In those cases, the costs were found to be similar to or less than the cost estimates without conversion. The analyses in this paper also show that estimated costs are highly dependent on the characteristics of the industrial emission source, the assumptions related to the type and price of energy used by the capture facilities and the economic parameters of the project such as the discount rate and capital costs. [ABSTRACT FROM AUTHOR]

Abstract: This paper investigates the role of CCS technologies as part of a portfolio for reducing CO2 emissions from the European electricity supply system until the year 2050. The analysis is carried out with the aid of a techno-economic model (with the objective to minimize the total system cost) including a detailed description of the present stationary European electricity supply system (power plants) and potential CO2 storage sites as obtained from the Chalmers Energy Infrastructure databases. The ability of different EU Member States and regions to facilitate and to benefit from CCS will most likely depend on local conditions in terms of current energy mix, fuel supply chains and distance to suitable storage locations. Special emphasis is therefore put on analyzing turn-over in capital stock of the existing power plant infrastructure, timing of investments and the infrastructural implications of large scale introduction of CCS on a regional perspective. The paper discusses the role of and the requirements on CCS for meeting strict CO2 emission reduction targets of 85% reduction from power generation by 2050 relative 1990 emissions in three different scenarios. All analysed scenarios apply the same cap on CO2 emissions. The first scenario includes a continued growth in electricity demand (as presented in EU base-line projections). The second scenario includes stated EU targets for 2020 and indicative targets for 2050 with respect to increased energy efficiency, and thus, considers a lower growth in electricity demand compared to the base-line. The third scenario includes EU targets (to 2020 and indicative targets to 2050) on energy efficiency, equal to the second scenario, and EU targets of electricity from renewables. The results show that it is possible for the European electricity generation system to meet an 85% CO2 reduction target by 2050 with a potentially large contribution from CCS. Up to 50% of the electricity generation will come from plants with CCS with a peak capture estimated to 1.8GtCO2 per year and cumulative CO2 capture of about 39GtCO2 between 2020 and 2050 (it is assumed that CCS will be commercially available from 2020). As expected, countries which currently have high carbon intensity and which are located nearby suitable storage sites will benefit the most from CCS implementation. Hence, the results suggest that Italy has the largest demand for CCS with annual peak capture at around 0.5GtCO2 in the base-line scenario. The model results indicate a steep ramp-up of CCS post-2020, which imposes challenges for timely investments in corresponding CCS infrastructure including transportation and storage. A continued growth in electricity demand can lead to demand for CCS to such extent (in the base-line capacity build up is about 300GW of CCS between 2020 and 2050) that the actual penetration level could be limited by fuel markets and power industries’ ability to supply fuel and CCS power plants. [Copyright &y& Elsevier]

Abstract: Emissions from electricity generation will have to be reduced to near-zero to meet targets for reducing overall greenhouse gas emissions. Variable renewable energy sources such as wind will help to achieve this goal but they will have to be used in conjunction with other flexible power plants with low-CO2 emissions. A process which would be well suited to this role would be coal gasification hydrogen production with CCS, underground buffer storage of hydrogen and independent gas turbine power generation. The gasification hydrogen production and CO2 capture and storage equipment could operate at full load and only the power plants would need to operate flexibly and at low load, which would result in substantial practical and economic advantages. This paper analyses the performances and costs of such plants in scenarios with various amounts of wind generation, based on data for power demand and wind energy variability in the UK. In a scenario with 35% wind generation, overall emissions of CO2 could be reduced by 98–99%. The cost of abating CO2 emissions from the non-wind residual generation using the technique proposed in this paper would be less than 40% of the cost of using coal-fired power plants with integrated CCS. [Copyright &y& Elsevier]

Abstract: This paper investigates the role of CO2 capture and storage (CCS) technologies as part of a portfolio for reducing CO2 emissions from the European electricity generation system until the year 2050. Special emphasis is put on the ramp-up of CCS with respect to timing of investments and requirement of corresponding CO2 transportation and storage infrastructure. The investigation comprises scenario analysis through modeling possible development of the electricity supply system for EU25 and together with a more detailed analysis of Northern Europe (Germany, UK, Denmark, Finland, Sweden and Norway). The modeling has been carried out with a techno-economic model (minimizing the system cost) including a detailed description of the present stationary European electricity generation system as obtained from the Chalmers Energy Infrastructure database. It is concluded that CCS can play a significant role in reducing CO2 emissions at a cost in the range of 20–60€/t over the period studied. In EU25 as much as 39Gt CO2 may be captured over the period 2020–2050 implying a steep ramp-up, i.e. most CCS capacity is added during the first two decades after 2020 from which it is assumed to be commercially available. Corresponding capture in Germany and UK amounts to 9 and 4Gt, respectively. The analysis show that a transportation infrastructure can be put in place for about 2–5€/t CO2. However, the steep ramp-up obtained from the model obviously do not take into account other issues which must be resolved for a large scale implementation of CCS. Examples of such issues are discussed in the paper and concern establishment of a legal framework regulating subsurface storage of CO2, inclusion of captured CO2 in the European Union emission trading scheme and issues related to fuel markets and fuel supply to accommodate an increased use of coal as a fuel. [Copyright &y& Elsevier]

Carbon Capture and Storage (CCS) has been viewed as an emission abatement option with great potential in China as coal has dominated China's energy consumption. China has already started to pay attention to CCS, as well as to the proposed the concept of ‘CCUS’ (which adds CO 2 Utilization into the chain of capture, transportation and storage). However, CCS is still in the early stages of its technological development, and the high cost, with several internal and external uncertainties make the role that CCS can play in China's future emission reduction unclear. From the perspective of general equilibrium analysis, this paper introduces CCS into a regional energy–economy–environment integrated assessment model, and makes a comprehensive evaluation of CCS's potential for future development and contribution to emission abatement in China. At climate policy level, the potential contribution of CCS in emission abatement has been evaluated against different future emission constraint scenarios in China. At technological level, the effects of endogenous learning and policy incentives on CCS have been investigated, and the substitution capacities of CCS and Non-hydro renewables to fossil energy have been discussed, as well as their technology penetration rates. Furthermore, the impact of CO 2 utilization on the development of CCS has also been discussed. [ABSTRACT FROM AUTHOR]

Currently, there are considerable discrepancies between China's central government and some local governments in attitudes towards coal to liquids (CTL) technology. Energy return on investment (EROI) analysis of CTL could provide new insights that may help solve this dilemma. Unfortunately, there has been little research on this topic; this paper therefore analyses the EROI of China's Shenhua Group Direct Coal Liquefaction (DCL) project, currently the only DCL commercial project in the world. The inclusion or omission of internal energy and by-products is controversial. The results show that the EROIstnd without by-product and with internal energy is 0.68-0.81; the EROIstnd (the standard EROI) without by-product and without internal energy is 3.70-5.53; the EROIstnd with by-product and with internal energy is 0.76-0.90; the EROIstnd with by-product and without internal energy is 4.13-6.14. Furthermore, it is necessary to consider carbon capture and storage (CCS) as a means to control the CO2 emissions. Considering the added energy inputs of CCS at the plant level, the EROIs decrease to 0.65-0.77, 2.87-3.97, 0.72-0.85, and 3.20-4.40, respectively. The extremely low, even negative, net energy, which may be due to high investments in infrastructure and low conversion efficiency, suggests CTL is not a good choice to replace conventional energy sources, and thus, Chinese government should be prudent when developing it. [ABSTRACT FROM AUTHOR]

• A bottom-up estimation of CO 2 mitigation potential of combined options for a case-study refinery. • A dynamic CO 2 mitigation potential over time is based on measure interactions for each pathway. • Co-processing account for 60% of the portfolio followed by CCS with 23%, GE with 7%, and H 2 with 6% • The oil and gas industry could reach carbon neutral operation at factory gate. • The methodological approach brings insights to define optimal transition routes of the industry. The oil and gas industry is responsible for 6% of total global CO 2 emissions, from exploration to downstream petrochemical production and account for another 50% when including the use of its products. Thus, this industry has a significant role in realising the target of net "zero" CO 2 emissions by 2070, essential to limit global warming to 1.8 °C [2], as introduced under the Paris agreement. Currently, the interactions of an extensive set of individual and combined CO 2 mitigation measures along the value chain and over time are poorly assessed. This paper aims to assess a bottom-up CO 2 mitigation potential for a complex refinery, including portfolios of combined mitigation options, considering synergies, overlap, and interactions over time for more realistic insight into the costs and constraints of the mitigation portfolio. A total of 40 measures were identified, covering a wide range of technologies such as energy efficiency measures (EEM), carbon capture and storage (CCS), bio-oil co-processing, blue and green hydrogen (BH 2 , GH 2), green electricity import, and electrification of refining processes linked to the transition of the Colombian energy systems. Five deployment pathways were assessed to achieve different specific targets: 1-base case scenario, 2-less effort, 3-maximum CO 2 avoidance, 4-INDC, and 5-measures below 200 €/t CO 2. Two scenarios (3 and 5) gave the highest GHG emission reduction potentials of 106% and 98% of refining process emissions, respectively. Although significant, it represent only around 13% of the life-cycle emissions when including upstream and final-use emissions of the produced fuels. Bio-oil co-processing options account for around 60% of the mitigation options portfolio, followed by CCS (23%), green electricity (7%) and green H 2 (6%). The devised methodological approach in this study can also be applied to assess other energy-intensive industrial complexes and shed light on the bias for estimating CO 2 mitigation potentials, especially when combining different mitigation options. This is turn is vital to define optimal transition pathways of industrial complexes. [ABSTRACT FROM AUTHOR]

In 2008, the Republic of Korea announced the Low Carbon Green Growth vision as the national growth engine. This Green Growth vision invested in developing state-of-the-art green technologies to minimize greenhouse gas and pollutant emissions. Following a change in administration, Korean green technologies were re-categorized into six core technologies for climate change response in 2014, and ten core technologies for carbon-neutrality in 2021. The government proposed the realization of an inclusive green state in the 3rd Five-Year Green Growth Plan announced in 2019. Following the Green New Deal announced in 2020, green technology policies and investments continue, with the declaration of 2050 carbon neutrality. In the past two years, government policies from the 2050 Carbon Neutrality Strategy to the 2050 Carbon-Neutral Scenario consider Carbon Capture Utilization and Storage (CCUS) as an important technology to reduce CO2 and meet carbon-neutral goals. This study examines major green technology policy trends, focusing on CCUS, beginning with the Green Growth era in 2008 to today. R&D investment costs related to green technology during the green growth period and CCUS-related investment costs over the past 10 years (2011–2020) are utilized in statistical analyses (correlation, trend) to investigate and analyze investment volatility in green and CCUS technologies related to climate change. Finally, the study will provide basic information for establishing CCUS-related R&D policies, which will continue to increase in achieving carbon neutrality. [ABSTRACT FROM AUTHOR]

Abstract: The purpose of this paper is to assess the timeline for capture and storage of carbon dioxide (CCS) by inverting the 450 Scenario of the IEA – especially the Blue Map Scenario – limiting the greenhouse gas emissions by 50–80% by 2050. In this pursuit, the critical stages of a new energy technology have been addressed. The timeline is considered in a global perspective on the basis of available prognoses for fossil fuels – especially coal. Relevant research questions are: (1) what generating capacity is required to meet the global demands, and (2) which capture rate would be realistic and sufficient. In answering these questions, the study employs two empirical “laws” that apply to new energy technology options in the transition and the stabilisation phase. This approach is used to determine the required scale-up rates and to compare efforts and impacts associated with prior experience from successful energy technologies implemented over the past century. Criteria are also suggested for coining CCS technology available and material with regard to commercial power generation. The study reveals some inherent limitations based on the perception that the energy system itself is so huge that it takes time to build the required human and industrial capacity, and to fill the knowledge gap. History suggests that 30years or more are needed for a new energy technology to materialise. In order for CCS to have the desired impact on greenhouse gas emissions by 2050, the process of materialising CCS must take place within just one decade. Hence, the implication is that broaching CCS into society within this short time span is – if practicable – an unprecedented challenge which requires war-like actions. [Copyright &y& Elsevier]

Abstract: The highly contentious, complex negotiations over the past several years to establish a globally more-inclusive, post-Kyoto Framework illustrate the daunting complexity and diversity of interests, which had to be accommodated. Notwithstanding the many challenges, a “Copenhagen Accord” was reached at the December 2009 15th Conference of Parties (COP 15) of the United Nations Framework Convention on Climate Change (UNFCCC) held in Copenhagen, Denmark. That Accord provided the basis for subsequent delineation of the post-Kyoto Framework in 2010 at the meetings in Mexico City, Mexico. Adoption of more flexibility in the approaches nations can employ to achieve significant, verifiable emissions reductions is among the many critical and necessary accommodations made to achieve more inclusive participation from developing economies and other large economies that did not adhere to the Kyoto Protocol. Negotiations also had to address trade and national sovereignty issues as well. This flexibility is an essential recognition of national and cultural differences including differences in levels of national and sub-national economic wealth and growth, status of energy infrastructure development, and national energy resource endowments. This paper presents research findings from a project using a step-by-step methodology. The first step was defining a set of generic, guiding principles for economically efficient and effective national emissions reduction programs. These were employed to design a comprehensive portfolio of innovative national policy and technology strategies that could be adopted by large, developed economies as well as some large developing economies. A specific example is presented using the United States as the test case. The cost-effectiveness of the innovative policy and technology portfolio is assessed for the test case based on a number of effectiveness measures, including: projected economic impacts and emissions reductions, national security impacts, energy-related impacts on water use and other environmental aspects, and regional economic equity. The assessment methodology employs a Reference Case Scenario (RCS), based on the Annual Energy Outlook 2010 energy projections (AEO 2010) of the U.S. Energy Information Agency (EIA), extended through 2050. The EIA energy projections are a widely used basis for projecting future energy demand, supply, and prices in the United States. They provide a comprehensive economy-wide reference data set. Particular attention is given to the electric generation, transportation, and industrial sectors, which account for the majority of energy production, demand, and emissions. A Policy and Technology Innovations Scenario (PTIS) is constructed covering all sectors of the energy economy with special attention as described above. The case specifications include new Federal and State legislative innovations and modifications to existing laws, regulatory reforms and innovations, and enhanced low-carbon technology innovation programs. Based on the PTIS case specifications, the incremental energy, economic, emissions, and other impacts from successful adoption and implementation of the PTIS case are projected as changes to the Reference Case Scenario using transparent techno-economic modeling approaches. The enhanced, low-carbon energy technology innovations programs included in the PTIS case cover a broad spectrum of energy supply and demand innovations. Particular attention is given to innovations that increase energy efficiency in both production and uses of energy in all economic sectors. Recognizing the extremely large energy infrastructure and imbedded capital investments already existing in the United States, special attention is given to innovations to transform and expand that infrastructure to meet future clean energy needs. The latter is a key strategy for making the transition affordable. One focus of attention is innovative opportunities for Carbon Capture and Sequestration (CCS). These are described along with the policy, regulatory, and technology improvements necessary to enable those contributions. The quantitative and qualitative differences between the two Scenarios are compared using the effectiveness measures adopted. These comparisons confirm that a portfolio such as that modeled in this project can lead to significant, affordable emissions reductions in the near term, and establish a pathway to a future energy economy with much larger reductions in energy use and emissions than the Reference Case in the longer term. Other key insights and conclusions from the assessment are described. The national and sub-national political, economic, and regulatory barrier and constraint challenges to successful implementation of a PTIS case are presented along with options for overcoming those challenges. [Copyright &y& Elsevier]

Abstract: This paper investigates how the European electricity generation system can meet deep cuts in CO2 emissions until the year 2050 with special focus on national conditions for CCS. An 85% reduction in CO2 emissions until 2050 is imposed. The analysis is carried out with a techno-economic model (minimizing the system cost) including a detailed description of the present stationary European electricity generation system (power plants) and potential CO2 storage sites as obtained from the Chalmers Energy Infrastructure Database. The modeling puts a cap on CO2 emissions from the system which gives a price on these emissions, i.e. similar to the effect of the European Emission Trading Scheme (EU-ETS), which is the main policy instrument for controlling GHG emissions within EU. Emphasize is put on analyzing turn-over in capital stock of the existing power plant infrastructure, timing of investments and the infrastructural implications of large scale introduction of CCS on a regional perspective, including the effect of investing in new transmission capacity between member states. The work compares two scenarios, one used in a previous work with significant growth in electricity consumption and one assuming that energy efficiency measures are successfully applied in line with the recent EU energy policy package. The results show that it is possible to meet an 85% CO2 reduction target by 2050 at a cost of some 50 to 80 € /ton CO2 over the period up to 2050, but this will require large contributions from CCS and electricity from renewable sources (mainly wind and biomass). Yet, without significant energy efficiency measures it is questionable if such large investments in generation technologies are feasible. Thus, to reach an 85% reduction in CO2 emissions from the electricity generation system by 2050 is not a matter of choice between different technologies and energy efficiency measures but all of these are required and the crucial point is if there will be a high enough price on CO2 emissions. [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: The International Energy Agency Energy Technologies Perspectives (ETP) model is used to assess the prospects for carbon abatement options, including carbon capture and storage, up to 2050. Three main scenarios are considered: a Baseline scenario with current energy policies, an accelerated technology scenario that seeks to return energy-related CO2 emissions in 2050 to their level in 2005, and a scenario for which CO2 emissions are reduced at 50% of current levels by 2050. To reach these emissions reduction targets, annual global CO2 emissions in the year 2050 must be reduced by 35 GtCO2 to 48 GtCO2 compared to the Baseline scenario. The analysis presented here shows that a broad portfolio of emissions reducing technologies will need to be deployed across all economic sectors of the global economy to reach these targets. Carbon dioxide capture and storage (CCS) is one of the suite of technologies employed across the globe to reach these targets. CCS adoption occurs in many aspects of the global economy and accounts for 14–19% of all emissions reductions. The total amount of CO2 captured and stored in deep geologic reservoirs up to 2050 ranges between 5.1 GtCO2 and 10.4 GtCO2 in these two climate policy scenarios. Up to 2030, more than half of total CCS deployment takes place in OECD countries. After 2035, emerging economies account for more than half of total CCS use. This paper also demonstrates that as the climate policy becomes more stringent it will be necessary for CCS to deploy more extensively in many different industries outside of the electric power sector which often receives the most attention in discussions of CCS''s role in addressing climate change. [Copyright &y& Elsevier]

Abstract: In this paper, different electricity demand scenarios for Spain are presented. Population, income per capita, energy intensity and the contribution of electricity to the total energy demand have been taken into account in the calculations. Technological role of different generation technologies, i.e. coal, nuclear, renewable, combined cycle (CC), combined heat and power (CHP) and carbon capture and storage (CCS), are examined in the form of scenarios up to 2050. Nine future scenarios corresponding to three electrical demands and three options for new capacity: minimum cost of electricity, minimum CO2 emissions and a criterion with a compromise between CO2 and cost (CO2-cost criterion) have been proposed. Calculations show reduction in CO2 emissions from 2020 to 2030, reaching a maximum CO2 emission reduction of 90% in 2050 in an efficiency scenario with CCS and renewables. The contribution of CCS from 2030 is important with percentage values of electricity production around 22–28% in 2050. The cost of electricity (COE) increases up to 25% in 2030, and then this value remains approximately constant or decreases slightly. [Copyright &y& Elsevier]

Abstract: The EU Emissions Trading Scheme (EU ETS) may prove a powerful incentive to advance operations of CO2 capture and storage (CCS) in the European Union, provided that the CO2 market price is sufficiently high and predictable, and CCS operations will be included in the scheme. This will require clear rules for accounting emissions from CCS installations. The European Commission aims to complement the 2007 Monitoring and Reporting Guidelines (MRGs) for the EU ETS with annexes for CCS operations. This paper presents insights gained from work on these MRGs. [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]

The present study aims to reduce carbon dioxide (CO2) emission from a CI engine using calcite/activated carbon-based post-combustion CO2 capture system fueled with Calophyllum inophyllum biodiesel (B100). The tests were conducted in a two-cylinder CI engine used in tractors at different load conditions. The performance and emission parameters of diesel and B100 with and without calcite and activated carbon-based CO2 capture system were studied. The results show that compared to diesel, CO2 emission increased by 19% for B100 due to high fuel-bound oxygen and carbon. Higher NO emission with a slightly reduced smoke opacity is observed with B100 combustion. CO2 emission is reduced with the CO2 capture system for both diesel and B100. CO2 emission is reduced by 11.5% and 7.3% for diesel with calcite and activated carbon, respectively, and reduced by 15.8% and 10.5% for B100 with calcite and activated carbon. Due to the adsorption capacity of both calcite and activated carbon, NO and smoke opacity are reduced considerably. The results display that calcite is better in reducing CO2 compared to activated carbon-based CO2 capture system. It is perceived that the combination of biofuel and calcite-based CO2 capture system can both reduce engine-out emissions and cause a net negative CO2 emission as it is renewable aiding in mitigation of global warming effects. [ABSTRACT FROM AUTHOR]

The main objective of this study is to characterise the electric power industry's CO2emissions and to understand its carbon capture and storage (CCS) prospects in China's Guangdong Province. Coal-fired power plants in Guangdong are the major point sources, contributing to more than 90% of CO2emissions of the electric power industry. The fossil-fuelled power plants are mainly located in the Pearl River Delta (PRD), and the newly built and planned large plants are mainly located in coastal zones. More basic research and investigation are necessary in the coming years to develop CCS. In the medium term, the harbours of eastern cities can be the key areas for CCS demonstration projects. In the long term, the reduction effect can be more remarkable if the CO2capture and pipeline project could be constructed on a large scale within the densest CO2point source area in the PRD. [ABSTRACT FROM AUTHOR]