Search

• Couples of multiparameter screening and compositional simulation are useful for site optimization for CO 2 -EOR and storage. • Miscible CO 2 flooding with one or two injection wells are the best operation for M10 reservoir. • Well pattern and bottom pressures of CO 2 injection control the mechanism and efficiency of CO 2 flooding. • HZ21-1 field has considerable potential for applying offshore CO 2 -EOR and CO 2 storage technology of Guangdong CCUS project. CO 2 -enhanced oil recovery (CO 2 -EOR) and storage is currently the most effective and economic technology for reducing CO 2 emissions from burning fossil fuels in large scale. This paper is the first effort of proposing a modelling assessment of CO 2 -EOR and storage in the HZ2-1 oilfield in the Pearl River Mouth Basin in northern South China Sea offshore Guangdong Province. We attempt to couple the multi-parameter dimensionless quick screening model and reservoir compositional simulation for optimization of site screen and injection simulation. Through the quick screening, the reservoirs are ranked by EOR dimensionless recovery R D , and by CO 2 storage in pore volume S CO2. Our results indicate that S CO2 is highly pressure dependent and not directly related to R D. Of these reservoirs, CO 2 -EOR and storage potential of the M10 was estimated through a compositional simulation as a case study based on a 3D geological model. Nine scenarios of CO 2 injection operations have been simulated for 20 years with different well patterns and injection pressures. The simulation results represent an obvious improvement in oil production by CO 2 flooding over No−CO 2 production. The best operation for M10 is miscible CO 2 flooding, which led to the higher recovery factors of 52%˜58% and CO 2 stored masses of 8.1×106˜10.8×106t. The optimum operation for CO 2 injection should be set well pattern in region of injector I1 and high injection pressure for miscible flooding. In a whole, the HZ21-1 field can be used as a candidate geological site for GDCCUS project. We are fully aware of the limitation in the primary modelling including reservoir and fluid properties and production history matching, and regard this study as a general and hypothetic proposal. [ABSTRACT FROM AUTHOR]

Strategic regional planning is an important step towards a successful CCUS development. This paper is the first effort of proposing a development plan of offshore CO 2 storage and transport for Guangdong in 2030 and 2050. We attempt to make an ambitious and achievable plan. The cluster-hub model of sources and sinks is adopted, and reuse of existing infrastructures is preferred. The targets of CCUS in Guangdong by 2050 are approximately 8% of the CCS targets that proposed for entire China (ADB, 2015), except a smaller target of 2050. The dual-phase and dual-track approach of ADB’s roadmap is followed. The CCUS phase I before 2030 is characterized by the capture of high-purity CO 2 from petrochemical industry and the storage of CO 2 mainly related to CO 2 -EOR. The target of ∼3 Mtpa CCUS in 2030 will be achieved by source-sink match A1. The phase II from 2030 to 2050 is characterized by a wider deployment of CCUS. The target of CCUS in Guangdong is ∼35 Mtpa in 2040 and ∼110 Mtpa in 2050, leading to the cumulative CO 2 avoidance of ∼187 MtCO 2 for 2031–2040 and ∼730 MtCO 2 for 2041–2050. Four source-sink matches are proposed for this phase, including the storage clusters in the Pearl River Mouth Basin and in the Beibuwan Basin in the northern South China Sea. Research with sufficient lead time to support the phased CCUS development is proposed, including databases, feasibility studies, technique R&D, cost estimation, and optimized system design. We are fully aware of the large uncertainty in the years ahead, and regard this planning as a highly general and hypothetic proposal. [ABSTRACT FROM AUTHOR]

Abstract: The cement manufacturing sector is the second largest source of anthropogenic greenhouse gas emissions in the world. Carbon Capture and Storage (CCS) is one of the most important technologies to decarbonise the cement manufacturing process. China has accounted for more than half of global cement production since 2008. This study suggests criteria to assess the potential to retrofit cement plants and analyses the economics of retrofitting cement plants for CCS with a case study of a modern dry process cement plant locating in Guangdong province, China. The study assumes the extra heat and power for CO2 capture and compression is provided by a new 200MW combined heat and power unit (CHP) (US$17.5/MWh thermal for the cost of coal). The estimated cost of CO2 avoidance by retrofitting a cement plant for carbon capture in 2012 is US$70/tonne at a 14% discount rate with 25years remaining lifetime. Through a stochastic cash flow analysis with a real option model and Monte Carlo simulation, the study found the value of an option to retrofit to be US$1.2million with a 7.3% probability of economic viability. The estimate is very sensitive to the assumptions in the carbon price model (i.e. base carbon price is US$12.00/tCO2e in 2012 and the mean growth rate is 8%). The option value and the probability can reach US$20 million and 67% respectively, if a 10% mean carbon price growth is assumed. Compared with post-combustion carbon capture retrofitting prospect in existing coal-fired power plants, the economics of retrofitting cement plants to carbon capture is less attractive. However, given the uncertainties in climate policy, regulation and carbon market, new-build cement plants in China, with long lifetime, should consider an essential level of “CCS Ready” to reduce the cost of retrofit and keep the retrofitting option open. [Copyright &y& Elsevier]

Abstract: China has been building approximately 1 GW of new coal-fired power plant per week since 2005. Power plants now in construction may continue to operate until 2040. “CCS (Carbon Capture and Storage) Ready” enables and eases the subsequent retrofitting of a plant to be able to capture carbon dioxide later in that plant’s lifetime. Building on the definitions of the IEA GHG (IEA Greenhouse Gas Programme) and GCCSI (Global Carbon Capture and Storage Institute), this study suggests a novel concept ‘CCS Ready Hub’ for implementing CCS Ready. A CCS Ready Hub not only includes a number of new coal-fired power plants but also integrates other existing stationary carbon dioxide emissions sources into the planning for potential infrastructure. We conducted a case study of Guangdong province in China with a detailed engineering and economic assessment in Shenzhen City. The study first reviewed the potential storage sites and analysed the existing stationary emissions sources in Guangdong using a GIS (Geographic Information System) approach. Thereafter, we focused on investigating the economic benefits of a ‘CCS Ready Hub’ at a potential 4 GW new USCPC (ultra-supercritical pulverised coal-fired) power plant in Shenzhen. Using the cost of carbon dioxide avoidance in 2020 as a criterion, we found that the concept of a CCS Ready Hub to finance CCS Ready at a regional planning level rather than at an individual plant is preferred since it significantly reduces the overall cost of building an integrated CCS system to reduce carbon emissions in the future. [Copyright &y& Elsevier]

Abstract: Making new coal-fired power plants carbon capture ready (Carbon Capture Ready) in China has been recognised as a crucial by a number of stakeholders academics, energy companies and regional government, based on a study in EU-UK-China NZEC project. A number of publications have investigated the definition, engineering requirements, economic and finance of CCR for China. However there remain a number of questions regarding the extent to which a plant’s physical location might constrain the feasibility of CCS retrofit. To address this issue, a Geographical Information System (GIS) has been used as a tool for mapping current and planned large carbon dioxide sources in Guangdong, also illustrating potential storage sites and calculating possible carbon dioxide transportation route. This paper investigates the location factors that should be considered when locating new build CCR power plants and demonstrates the methodology of using GIS software with spatial analysis in planning new build power plant in Guangdong. A preliminary study has identified over 30 large power plants within the region, with plant locations and historical emission data collected and presented in ArcGIS. Factors such as distance to potential storage site, route of CO2 pipeline, extra space on site and potential development plan etc. were investigated in the modelling and calculated the potential source and sink solution. The study then moves on to suggest possible new build plant locations which can be easily fitted in to the current network, based on economic optimisation. The scope for future coal plant development combined with a possible nuclear plant siting plan is discussed towards the end of the paper. Guangdong province, which owns the third largest coal-fired power installed capacity out of 31 provinces, generated over 8% of China’s total electricity every year for the past 15 years. CO2 storage opportunities could be found in the surrounding South China Sea, where Guangdong has a total of 4,300 km of coastline and some small scale oil fields on shore within the region. It is also among the first places to start the national open and reform policy in China. The province is one of the richest in China, with the highest GDP among all other provinces since 1989, and the foreign trade accounts for more than a quarter of China’s total amount. It also contributes around 12 of the total national economic output. Currently, the provincial government is proposing a low carbon roadmap, which is the first of its kind in China. The work has created a totally new thinking on capture ready power plant planning. This differs from existing studies (e.g., which aim to investigate the existing carbon dioxide emission sources at specified location and provide source and sink matching analysis. Instead the study focuses on policy implementation for new build capture ready power plants. Three clusters within Guangdong province are identified as potential temporary CO2 storage hubs before transporting the gas to a long term storage site. When officials are planning new power plant locations from a capture ready perspective, the plants should not necessarily be close to storage sites in straight line, but rather should be within a reasonable distance of a cluster. Transport of the captured CO2 will not be limited to pipelines, but could be extended to road and rail tankers. Power plant parameters and storage site data were collected for this research. Public transportation, utilities, landscapes, river, land used and population data were referenced from various sources; therefore, some of the data could be out of date. Nevertheless, it should still provide enough information when deciding the location of the transport cluster. Any future work could build on the existing model with updated data. Moreover, it could fit in with the national natural gas transportation network and utility planning network to provide long term integrated energy system analysis. The paper could provide policy makers, investors and urban planning officials with a view on how conventional thermal power plant investment and planning could be optimised, using Carbon Capture Ready designs, to keep the CCS retrofitting option open. [Copyright &y& Elsevier]

A capture option is an option contract where the option holder can exercise a contract to retrofit an existing fossil fuel plant to capture carbon dioxide (CO2) on or before a fixed date. We suggest that new thermal power plants, particularly those in developing countries, consider issuing capture options at the design stage, because the sellers—the owners of newly built thermal power plants—may then invest in making these plants CO2 capture ready (CCR) to optimise returns from selling capture options. In a detailed case study on a 600 MW ultrasupercritical pulverised coal-fired power unit a potential storage site in Guangdong, China, the value of a capture option and CCR investment is evaluated using the backward deduction option pricing method through a stochastic cash flow model with Monte-Carlo simulations. If the power plant is retrofittable without CCR investment, then for an 8% discount rate the value of a capture option is US$11 million before CCR investment, Investing US$3.8 million in CCR increases the value of the capture option by an estimated US $12 million. Perhaps more important from a policy point of view, CCR investment can reduce the odds of early closure by 20% and also increase the chance of retrofitting to capture by 43%. If the power plant is not retrofittable in the absence of CCR design modifications, CCR investment to avoid 'carbon lock-in' is not only important for climate policy but is also economic from an investment point of view. We also conduct sensitivity analyses on a range of key assumptions to test the robustness of the findings. [ABSTRACT FROM AUTHOR]

In this paper, the immiscible water-alternating-CO2 flooding process at the LH11-1 oilfield, offshore Guangdong Province, was firstly evaluated using full-field reservoir simulation models. Based on a 3D geological model and oil production history, 16 scenarios of water-alternating-CO2 injection operations with different water alternating gas (WAG) ratios and slug sizes, as well as continuous CO2 injection (Con-CO2) and primary depletion production (No-CO2) scenarios, have been simulated spanning 20 years. The results represent a significant improvement in oil recovery by CO2 WAG over both Con-CO2 and No-CO2 scenarios. The WAG ratio and slug size of water affect the efficiency of oil recovery and CO2 injection. The optimum operations are those with WAG ratios lower than 1:2, which have the higher ultimate oil recovery factor of 24%. Although WAG reduced the CO2 injection volume, the CO2 storage efficiency is still high, more than 84% of the injected CO2 was sequestered in the reservoir. Results indicate that the immiscible water-alternating-CO2 processes can be optimized to improve significantly the performance of pressure maintenance and oil recovery in offshore reef heavy-oil reservoirs significantly. The simulation results suggest that the LH11-1 field is a good candidate site for immiscible CO2 enhanced oil recovery and storage for the Guangdong carbon capture, utilization and storage (GDCCUS) project. [ABSTRACT FROM AUTHOR]