Mt Of CO2 Research Articles

Revisiting the Utsira Saline Aquifer CO2 Storage Resources Using the SRMS Classification Framework

One major challenge for the CCS industry is to understand if CO2 geological storage can be implemented at the scale needed to address the climate change issue. Indeed, a high variability in CO2 storage resource estimates is encountered in the literature. To address this variability and provide more confidence in global and regional resource assessments, the Storage Resource Management System (SRMS) was developed by the Society of Petroleum Engineers (SPE). The SRMS provides guidelines on how to classify CO2 storage resources using both an uncertainty scale and a maturity scale. We apply the SRMS to the Utsira formation, as Utsira has been widely studied for CO2 storage and since the Sleipner operation, injecting up to 1 Mt of CO2 per year since 1996, provides a degree of validation. The range of the storage resource estimates is primarily assessed by evaluating different storage concepts: storage in structural traps, through residual trapping, or the effects of a limiting value for overpressure. The major uncertainties attached to these concepts are well known and further work is needed to incorporate resource estimates into an uncertainty framework in order to understand the spread in these estimates and to identify the best appraisal strategy to narrow that range.

Response of electricity sector air pollution emissions to drought conditions in the western United States

Water is needed for hydroelectric generation and to cool thermoelectric power plants. This dependence on water makes electricity generation vulnerable to droughts. Furthermore, because power sector CO2 emissions amount to approximately one third of total US emissions, droughts could influence the inter-annual variability of state- and national-scale emissions. However, the magnitude of drought-induced changes in power sector emissions is not well understood, especially in the context of climate mitigation policies. Using multivariate linear regressions, we find that droughts are positively correlated to increases in electricity generation from natural gas in California, Idaho, Oregon, and Washington; and from coal in Colorado, Montana, Oregon, Utah, Washington, and Wyoming. Using a statistical model, we estimate that this shift in generation sources led to total increases in regional emissions of 100 Mt of CO2, 45 kt of SO2, and 57 kt of NOx from 2001 to 2015, most of which originated in California, Oregon, Washington, and Wyoming. The CO2 emissions induced by droughts in California, Idaho, Oregon, and Washington amounted to 7%–12% of the total CO2 emissions from their respective power sectors, and the yearly rates were 8%–15% of their respective 2030 yearly targets outlined in the Clean Power Plan (CPP). Although there is uncertainty surrounding the CPP, its targets provide appropriate reference points for climate mitigation goals for the power sector. Given the global importance of hydroelectric and thermoelectric power, our results represent a critical step in quantifying the impact of drought on pollutant emissions from the power sector—and thus on mitigation targets—in other regions of the world.

Relevancy of Emission Reduction Fund (ERF) policy towards large-scale deployment of carbon capture technology in black coal-fired power plant

This study implements a single objective multi-constrained optimisation technique to evaluate the relevance of large scale deployment of post-combustion CO2 capture (PCC) technology as an emissions reduction fund (ERF) ‘project’ for black coal power generation in Australia. We target maximum net operating revenue, by generating forecasts of power plant load and CO2 capture rate, and while subject to the dual operational and environmental constraints. Four different hypothetical Australian Carbon Credit Unit (ACCU) prices ($AU 5, 15, 25 and 50/tonne CO2) are evaluated, through a single objective multi-constrained optimisation algorithm, for a 7-year contract period between 2016 and 2020 and with a 7.1 MT CO2 of emission baseline. The results indicate that at ACCU price of $AU 25/tonne CO2 (Scenario 3), represents a feasible solution for future deployment of PCC technology under ERF project settings. Across the contract period, PCC plant captures 90% CO2 from the power plant emissions with total plant net operating revenue at approximately $AU 1,765 million. The gross revenue gains from ERF incentive and selling of electricity are at 25% and 75% respectively. These findings point to the value of this computational approach for power plant operators in Australia considering low emissions technologies (viz. PCC) as ERF projects, aiding in their short and medium-term planning. Such an approach is extendable to other countries and regions under varying emissions trading schemes.

Geological characterization and numerical modelling of CO2 storage in an aquifer structure offshore Guangdong Province, China

The Lufeng (LF) 2-1 structure, which is the largest anticlinal structure developed in the Zhu I depression of the Pearl River Mouth Basin, offers high-quality source-sink matching with onshore CO2 emissions. In this paper, a 3D model using the TOUGH2/ECO2N tool was developed based on typical formation parameters obtained from a review of well and seismic structural data. Numerical results indicated that doubling the injection quantity does not result in a doubling of the CO2 distribution, which suggests the presence of nonlinear variations between the two variables. The CO2 plumes remain within the LF2-1 structural trap based on injection rates of either 1 Mt/y or 2 Mt/y. The maximum increase in formation pressure is less than 2 bars, which is 0.9% of the primary formation pressure. Therefore, the reservoir and seal properties of LF2-1 are optimal, which suggests that the prospect of injecting and storing a total of 40 Mt of CO2 is good. Overall, the LF2-1 may be used as a suitable offshore site for large-scale storage of industrial CO2 in deep saline aquifers. Additionally, the findings can guide site selection decisions in Guangdong Province for offshore CO2 geological storage demonstrations.

Modeling the multiple benefits of electricity savings for emissions reduction on power grid level: A case study of China’s chemical industry

Industry is a large electricity user. China’s chemical industry (globally the largest based on sales) contributes 7% to China’s GDP, while it consumes 11% of the total electricity consumption in industry and is responsible for 40% of total CO2eq, 40% of SO2, 59% of NOx and 18% of PM-emissions of the chemical industry emissions. The heterogeneity of GHG and air pollutant emissions across electricity grids (within a country) is rarely included in analyses. In this paper, electricity conservation supply curves are developed (distinguishing the grids) to estimate the cost-effective and technical potentials of electricity conservation in China’s chemical industry. The emission factors per grid for GHG (i.e. CO2, CH4 and N2O) and air pollutants (i.e. SO2, NOx and PM2.5) are calculated and used to quantify the emissions mitigation achieved by electricity saving technologies in the chemical industry for the period 2012–2035. Results show that significant multiple benefits can be obtained by implementing electricity efficiency measures. There are large differences among the six grids in terms electricity savings and emissions abatement of GHG and air pollutants. 83% of the total electricity saving potential is contributed by the North, Northwest and Central grids, equal to 32% of baseline electricity consumption in 2035. In 2035, 129 Mt of CO2, 33 kt CO2eq of CH4, 571 kt CO2eq of N2O, 235 kt of SO2, 275 kt of NOx and 52 kt of PM2.5 in these three grids can be avoided as a result of electricity savings (a reduction of 31–33% compared to baseline emissions). When decision-makers set targets for energy saving and emission reduction, the multiple benefits and grid heterogeneity should not be ignored.

The Carbon Dioxide-Rumen Fermentation Processes-strategy, a proposal to sustain environmentally friendly dairy farms

A novel Carbon Dioxide Utilization (CDU) approach from a relatively minor biogenic carbon dioxide emission source, Rumen Fermentation Processes (RFP), is presented. The CO2-RFP strategy explores the potential treatment of the liquid manure storage located at the bottom of the dairy barns with CO2-enriched air coming from cattle exhalation and belching to produce an important fertilizer such as NH4HCO3 (ABC, ammonium bicarbonate). The unusual CDU strategy, analyzed exclusively from a chemical point of view, could yield over 31.6 Million of tones, Mt, of ABC in aqueous solution using c. 18.0 Mt of CO2 and capturing c. 6.9 Mt of NH3, ammonia. This process would consume less energy than the traditional synthetic method (ABC fertilizer process) and would not produce any by-products or chemical compounds which may enter into conflict with the dairy sector. The quantity of ABC obtained by this strategy would be equivalent to four times the world production per year.Taking into consideration only the most relevant dairy countries, the estimate of the CO2negative emission achieved suggests a capture of around 1.8 Gt of CO2 equivalents and 82.8 Mt of NH3 from now to 2030. With the aim of providing a realistic outlook on the CO2-RFP strategy, the proposal is discussed considering a number of possible scenarios: the CO2-RFP strategy (1) in a typical livestock dairy farm, (2) in the most relevant dairy countries and (3) as a N-fertilizer supplier.

Potential climate change mitigation of Indian Construction Industry through a shift in energy efficient technology by 2050

Abstract. Climate change is a growing concern that is attracting international efforts. India, as a developing country, has committed to reducing its emission intensity of GDP up to 30 %–35 % by 2030. The emission intense sectors would be targeted to achieve climate commitment. One of the emission intense sector is construction raw material manufacturing that contributes 10 % share in the total emissions making it one of the potential mitigation sector. The study examines emissions from the construction raw materials namely, cement, steel, and brick manufacturing and presents two emission scenarios up to 2050. Energy efficient scenario (S2) is compared with a reference scenario (S1) developed based on a bottom-up approach. The results indicate that a moderate energy efficiency improvements and technological shifts lead to a decrease in emissions of 72 MT CO2 by 2030 and 137 MT CO2 by 2050. Further, the steel industry has the highest reduction potential, as the current technologies are energy inefficient. Similarly, the current dependency on fired bricks may be shifted to cement setting blocks leading to emission reductions. Cement manufacturing, on the other hand, shows limited scope for emission reduction that may be achieved through energy efficiency improvements. Efforts towards energy efficiency improvements in construction raw material manufacturing would result in reductions beyond the existing commitment of the Paris Agreement for India by 2030.

The CCS hub in Norway: some insights from 22 years of saline aquifer storage

The development of industrial-scale CCS in Norway, starting with the Sleipner project in 1996, gives a uniquely long track record of experience with CCS and provides valuable insights for the projected global growth in CCS. By the end of 2017, the Sleipner and Snøhvit CCS projects had captured and stored 22 Mt of CO2 in saline aquifers offshore Norway. CO2 plume monitoring observations at Sleipner can be used to indicate an overall storage efficiency of around 5% of the pore volume, with approximately one tenth of this volume dissolved in the brine phase. These estimates are consistent with the fluid dynamics of CO2 injection in which a gravity dominated processes are expected to give efficiencies in the range of 1-6%. Future projects may be able to find ways of improving these efficiencies.

Evaluation and mitigation of cement CO2 emissions: projection of emission scenarios toward 2030 in China and proposal of the roadmap to a low-carbon world by 2050

Much attention is being paid toward reducing the carbon dioxide (CO2) emissions associated with China’s cement production. However, as part of China’s international commitment to reduce carbon intensity, the inter-annual changes and driving forces behind CO2 emissions must be determined for the 2001–2015 period, along with the projection of the cement-related CO2 emissions until 2030. The objective of this article is to analyze the CO2 emission factors (EFs) and CO2 emissions from 2001 to 2015, project CO2 emission scenarios of China’s cement industry until 2030, and propose a low-carbon roadmap for the global cement industry by 2050 based on a series of practical reduction measurements performed by China. The results of our study indicate that CO2 EFs in 2015 were 55.36% lower than those in 2001, but CO2 emissions were 72.90% higher than those in 2001. The main reason for the decreasing total active CO2 EFs are policies enacted by the Chinese government regarding the removal of excess capacity and elimination of backward capacity as well as the technological innovation and ongoing annual reductions in the clinker-to-cement ratio (C/CR). Meanwhile, the driving force behind the increased cement-related CO2 emissions was the substantial growth in cement output. Scenarios regarding CO2 emissions by 2030 show an uncertainty regarding CO2 emissions, ranging between 3.51 and 11.70%, and CO2 EFs are expected to be 59–69% lower than those in 2005. CO2 emissions from the global cement industry from 2020 to 2050 based on CO2 capture, utilization, and storage (CCUS); utilization of alternative raw materials (ARMs) and alternative fossil fuels (AFFs); and technological innovation account for 39.3, 29.3, 24.7, and 6.7% of the CO2 reduction capability, respectively. It is possible to reduce ~ 1524 Mt of CO2, and the global optimal emissions by 2050 are ~ 2082 Mt of CO2.

Mission Innovation task force reports on enabling Gigatonne-scale CO2 storage

Mission Innovation task force reports on enabling Gigatonne-scale CO2 storage

Potential of Russian Regions to Implement CO2-Enhanced Oil Recovery

The paper assesses the techno-economic potential of Russia to implement carbon capture and storage technologies that imply the capture of anthropogenic CO2 and its injection into geologic reservoirs for long-term storage. The focus is on CO2 enhanced oil recovery projects that seem to be the most economically promising option of carbon capture and storage. The novelty of the work lies in the formulation of a potential assessment method of CO2 enhanced oil recovery, which allows for establishing a connection between energy production and oil extraction from the viewpoint of CO2 supply and demand. Using linear optimization, the most promising combinations of CO2 sources and sinks are identified and an economic evaluation of these projects is carried out. Based on this information, regions of Russia are ranked according to their prospects in regards to CO2 capture and enhanced oil recovery storage. The results indicate that Russia has a significant potential to utilize its power plants as CO2 sources for enhanced oil recovery projects. It has been estimated that 71 coal-fired power plants, and 185 of the gas-fired power plants of Russia annually produce 297.1 and 309.6 Mt of CO2 that can cover 553.4 Mt of the demand of 322 Russian oil fields. At the same time, the total CO2 storage capacity of the Russian fields is estimated at 7382.6 Mt, however, due to geological and technical factors, only 22.6% can be used for CO2-EOR projects. Of the 183 potential projects identified in the regional analysis phase, 99 were found to be cost-effective, with an average unit cost of € 19.07 per ton of CO2 and a payback period of 8.71 years. The most promising of the estimated regions is characterized by a well-developed energy industry, relatively low transportation costs, numerous large and medium-sized oil fields at the final stages of development, and favorable geological conditions that minimize the cost of injection. Geographically, they are located in the North-Western, Volga, and Ural Federal districts.

Estimating air pollution transfer by interprovincial electricity transmissions: The case study of the Yangtze River Delta Region of China

Abstract Interprovincial electricity transmissions have profoundly affected the emission patterns of air pollutants and greenhouse gases in China. Here, we estimate the air pollution transfer by interprovincial electricity transmission, taking Yangtze River Delta Region (YRDR) of China as an example. The results show that the YRDR received 153.01 billion kWh of electricity from other regions in 2015, accounting for 13.06% of its total electricity consumption; these other regions mainly included Sichuan, Shanxi, Hubei, Henan and Fujian. Air pollutants emissions, including 20.50 kt of SO2, 22.40 kt of NOX, 4.30 kt of dust, and 39.23 Mt of CO2, were transferred to generation-side regions by electricity transmissions, of which 34% were transferred to Shanxi, 31% to Sichuan, and 29% to Hubei. Then, different schemes to achieve interregional compensation were explored and compared based on previous studies and a 2015 simulation scenario. Direct electricity purchasing can promote renewable energy development but is the most cost, while pollutants emission trading is a scheme to promote the establishment of a reliable and efficient market. It is suggested that integrated schemes will promote collaboration between generation regions and consumption regions to realize sustainable targets on both sides.

Techno-Economy Analysis by Green Abatement Cost Curve for Pulp and Paper Industry

the production and expansion potential of Pulp and Paper Industry is an important indicator of social and economic development. The Pulp and Paper Industry is one of the largest carbon dioxide (CO2) emitters in world manufacturing. The industry emits GHG emissions around 10% or approximately 20.5 Mt of CO2 by Thai manufacturers. Investigations of GHG abatement using CO2 Abatement Cost Curves (ACC) can be used as a tool for investigating GHG reduction measures and technologies in the Pulp and Paper Industry. The results of this study assesses the cost-effectiveness and the total technical potential for carbon dioxide emission reduction in this sector.

Evaluation of CO2 enhanced oil recovery and CO2 storage potential in oil reservoirs of Bohai Bay Basin, China

The Bohai Bay Basin is the largest petroliferous sedimentary basin in China. This basin is encompassed by the Bohai Sea economic zone where a large volume of CO2 is emitted directly into the atmosphere without any treatment. Meanwhile, most of the oil and gas provinces in this basin are facing the selection of tertiary recovery technologies after the completion of water flooding. CO2 enhanced oil recovery (CO2-EOR) is an optimal choice for achieving both a reduction in CO2 emissions and enhanced (or improved) oil recovery. In this paper, an evaluation of the CO2-EOR and CO2 storage potential was carried out at the reservoir scale, based on an established oil reservoir database from numerous data sources, to provide the basis investigating CO2-EOR site selection and regional CO2 emission reduction in China. Moreover, an assessment scheme for the oil reservoirs in the Bohai Bay Basin was also proposed. The results showed that 613 CO2-EOR candidate oil reservoirs, including 354 miscible CO2-EOR candidate oil reservoirs and 259 immiscible CO2-EOR candidate oil reservoirs were identified by applying the screening methodology to 2,891 oil reservoirs in the Bohai Bay Basin. It was predicted that 683 Mt of additional oil can be produced from the CO2-EOR candidate oil reservoirs, and simultaneously 1,345 Mt of CO2 would be incidentally stored in these candidate oil reservoirs. Furthermore, the most prospective area is the miscible CO2-EOR candidate oil reservoirs in the Shengli oil and gas province, where 140 Mt oil could be produced with the CO2-EOR and the injection and incidental storage of 225 Mt of CO2.

KOSOVO FLY ASH: UTILIZATION IN CONCRETE AS PARTIAL CEMENT SUBSTITUENT AND THE ENVIRONMENTAL IMPACT

In Kosovo, except electrical energy, thermal power plants (TPP) annually produce more than 1.5 Mt of solid waste: Fly Ash (FA) and Bottom Ash (BA). Kosovo’s construction sector annually consumes around 1 Mt of cement. The environmental impact from cement production (consumption) is the emission of around 1 Mt of CO2. The focus of this study is the utilization of FA in concrete as cement replacement, which will indirectly mitigate the CO2 emissions from cement production. The properties of concrete with FA were investigated. For determining the optimum quantity of FA in concrete, four concrete mixes with different content of class C FA were tested. Density and consistence tests of FA fresh concrete, as well as tests of mechanical properties: compressive, tensile and splitting strength of FA hardened concrete specimens were performed. Concrete resistance to permeability was tested by measuring the depth of water penetration under hydrostatic pressure. The correlation between test results of concrete specimens with FA to reference concrete without FA was done. A 30% cement replacement by fly ash showed experimentally to be reasonable. The environmental benefit would be twofold: indirect decrease of 300,000 t of CO2 and removal of 125,000 m3 of industrial waste (FA).

A Review on Waste Management Options to Lessen Greenhouse Gas Emissions from Paper

This study hired a spreadsheet model to simulate the greenhouse gas emissions (GGEs) from the newspaper production and intake system. The GGEs made by newspaper in Australia during 1994/95 were equal to about 13.5Mt of CO₂, related to almost 2.5% of Australia's emission total. Over fifty percent of the amount contains CH4 emissions from landfilled waste material paper. Misuse management options effective in minimizing GGE emissions from the newspaper life-cycle include incineration with energy restoration (most reliable), newspaper recycling, landfill gas restoration and composting. These studies can be expanded to other wood-based and organic and natural wastes.

Conceptual design of multi-source CCS pipeline transportation network for Polish energy sector

The aim of this study was to identify an optimal CCS transport infrastructure for Polish energy sector in regards of selected European Commission Energy Roadmap 2050 scenario. The work covers identification of the offshore storage site location, CO 2 pipeline network design and sizing for deployment at a national scale along with CAPEX analysis. It was conducted for the worst-case scenario, wherein the power plants operate under full-load conditions. The input data for the evaluation of CO 2 flow rates (flue gas composition) were taken from the selected cogeneration plant with the maximum electric capacity of 620 MW and the results were extrapolated from these data given the power outputs of the remaining units. A graph search algorithm was employed to estimate pipeline infrastructure costs to transport 95 MT of CO 2 annually, which amount to about 612.6 M€. Additional pipeline infrastructure costs will have to be incurred after 9 years of operation of the system due to limited storage site capacity. The results show that CAPEX estimates for CO 2 pipeline infrastructure cannot be relied on natural gas infrastructure data, since both systems exhibit differences in pipe wall thickness that affects material cost.

Tracking the interaction between injected CO2 and reservoir fluids using noble gas isotopes in an analogue of large-scale carbon capture and storage

Industrial scale carbon capture and storage technology relies on the secure long term storage of CO2 in the subsurface. The engineering and safety of a geological storage site is critically dependent on how and where CO2 will be stored over the lifetime of the site. Hence, there is a need to determine how injected CO2 is stored and identify how injected CO2 interacts with sub-surface fluids. Since July 2008 ∼1 Mt of CO2 has been injected into the Cranfield enhanced oil recovery (EOR) field (MS, USA), sourced from a portion of the natural CO2 produced from the nearby Jackson Dome CO2 reservoir. Monitoring and tracking of the amount of recycled CO2 shows that a portion of the injected CO2 has been retained in the reservoir. Here, we show that the noble gases (20Ne, 36Ar, 84Kr, 132Xe) that are intrinsic to the injected CO2 can be combined with CO2/3He and δ13CCO2 measurements to trace both the dissolution of the CO2 into the formation water, and the interaction of CO2 with the residual oil. Samples collected 18 months after CO2 injection commenced show that the CO2 has stripped the noble gases from the formation water. The isotopic composition of He suggests that ∼0.2%, some 7 kt, of the injected CO2 has dissolved into formation water. The CO2/3He and δ13CCO2 values imply that dissolution is occurring at pH = 5.8, consistent with the previous determinations. δ13CCO2 measurements and geochemical modelling rule out significant carbonate precipitation and we determine that the undissolved CO2 after 18 months of injection (1.5 Mt) is stored by stratigraphic or residual trapping. After 45 months of CO2 injection, the noble gas concentrations appear to be affected by CO2-oil interaction, overprinting the signature of the formation water.

Algerian energy policy and potential to reducing greenhouse gas emissions

ABSTRACTIn Algeria, energy consumption is growing rapidly. Due to the high demand and declining conventional energy resources, the country developed a new energy policy based on the promotion of renewable energies and CO2 mitigation. For this purpose, the authorities have taken new steps to reinforce the legislative and institutional framework and put in place a favorable financial support. In addition, an ambitious program to develop solar energy and energy efficiency was adopted recently. The objective of this strategy is to achieve by 2030 a 40% share of solar electricity and to contribute, voluntarily, to reducing greenhouse gas (GHG) emissions. In this work, we present an analysis of the current situation and its projection to 2030 and we examine the available opportunities to reduce significantly GHG emissions. The study presents the magnitude of emissions in 2008 and 2012, the temporal evolution of CO2 and particularly what will be the impact on GHG emissions of the new strategy. The results show that, in 2012, GHG emissions totaled 153 MT CO2 eq. and growing at a rate of over 3%. However, there is a high potential for mitigation, especially in energy sectors, in building, transportation, as well as waste management and gas flaring. Two scenarios are developed: with implementation of solar energy and without. This analysis shows that the overall potential of CO2 mitigation will rise in 2030 to about 300 MT CO2 eq.

Bottom-up analysis of energy efficiency improvement and CO2 emission reduction potentials in the Swiss cement industry

The cement industry is among the top three industrial energy consumers in Switzerland with a share of 9% of the total final energy demand by Swiss industry in 2014. It is also a major contributor to the Swiss greenhouse gas emissions, releasing approximately 2.7 Mt of CO2 in 2014 (including both fossil and mineral CO2). This study investigates the energy efficiency improvement and CO2 abatement potential in the Swiss cement industry by means of energy efficiency cost curves. The energy savings potential for this sector is estimated based on the data collected from literature and via interviews with the experts. The current economic potential for final energy savings and CO2 abatement is estimated at 14% and 13% of the sector's final energy use and CO2 emissions in 2014 respectively and the total investment costs are approximately CHF ∼120 million (approx. USD 115 million). This study also highlights techno-economic barriers that are limiting implementation of the best practices in Swiss cement plants. Due to the relatively low current final energy and CO2 prices, the cost savings of the cost-effective measures are found to be low to very low. While the sensitivity to higher fuel prices (+50%) is limited, a CO2 tax of 84 CHF/t CO2 (approx. 80 USD/t CO2) would make carbon capture and storage economically viable and allow to drastically reduce CO2 emissions. The results of this study offer a better understanding of the energy efficiency gap in the sector and can serve as basis for formulating more effective policies.