International Journal of Greenhouse Gas Control最新文献

{"title":"CO2 transport and storage potential in the Caribbean Sea, Colombia","authors":"Lorena Suárez Bermúdez ,&nbsp;Luis Ramirez Camargo ,&nbsp;Edgar Yáñez ,&nbsp;Filip Neele ,&nbsp;André Faaij","doi":"10.1016/j.ijggc.2025.104361","DOIUrl":"10.1016/j.ijggc.2025.104361","url":null,"abstract":"<div><div>Carbon Capture and Storage (CCS) can be a decarbonisation alternative for heavy industry and fossil fuel power plants in the Caribbean region in Colombia. This study assesses the techno-economic potential of transporting and storing CO₂ in the Colombian Caribbean Offshore. A methodological framework was developed to estimate the geological CO₂ storage potential on a basin scale as well as the associated transport and storage costs. The results show that Guajira Basin is the most suitable for CO₂ storage in the study area, with estimated storage resources of 3.2 Gt in the most promising areas. These resources exceed Colombia's yearly emissions, related to industry and power generation, by a factor of 177, indicating ample CO₂ storage potential.</div><div>The transport and storage costs range between 3.2 and 48 €/tCO₂ depending on the transport option, CO₂ flow rate, source-to-sink distance and type of sink (gas reservoir or aquifer). Shipping is the most expensive alternative among the transport options but can compete with offshore pipelines when distances are longer than 400 km and for 2.5 Mtpa of transported CO₂. This study provides valuable data to industrial emitters and policymakers about the potential of CCS in mitigating emissions in the Caribbean region's heavy industry and power sector, as well as the technology potential in a large-scale deployment scenario.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"144 ","pages":"Article 104361"},"PeriodicalIF":4.6,"publicationDate":"2025-03-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143739177","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"The advantages of reheated and intercooled gas turbines for combined cycles with post-combustion CO2 capture and storage","authors":"Andrea Zelaschi,&nbsp;Davide Bonalumi,&nbsp;Paolo Chiesa,&nbsp;Emanuele Martelli","doi":"10.1016/j.ijggc.2025.104345","DOIUrl":"10.1016/j.ijggc.2025.104345","url":null,"abstract":"<div><div>This study investigates the efficiency and economic performance achievable by combined cycles with post-combustion CO₂ capture, employing different strategies to increase the concentration of CO₂ in the flue gases. These expedients include reheating in the gas turbine expansion, intercooling of the compression, and supplementary firing at the inlet of the heat recovery steam generator. The power block is modelled by using GS, a software developed at Politecnico di Milano, and the models are calibrated against data from commercial gas turbines. The amine-based CO₂ capture and compression system are simulated with a validated model implemented in Aspen Plus software. The analysis shows that, compared to the standard H-class combined cycle, reheating and intercooling slightly improve the efficiency with and without CO₂ capture (rising from 63% to 63.6-64.4% without capture and from 55.5% to 56.1-57.1% with CO₂ capture). A further important advantage of reheating and intercooling is the significant (up to 10%) decrease in the plants' specific investment cost ($/kW), especially for CO₂ capture plants. The best option for efficiency and costs involves a combination of intercooling and reheating, achieving a 4.5% reduction in the cost of electricity compared to the H-class standard cycle. The introduction of supplementary firing, in addition to reheating, further lowers the specific plant cost but negatively impacts efficiency and the cost of electricity.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"144 ","pages":"Article 104345"},"PeriodicalIF":4.6,"publicationDate":"2025-03-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143697966","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"A novel efficiency-based, tiered carbon storage incentive approach for CCUS through CO2 enhanced oil recovery and storage","authors":"Abouzar Mirzaei-Paiaman ,&nbsp;Larry W. Lake ,&nbsp;Lorena G. Moscardelli","doi":"10.1016/j.ijggc.2025.104362","DOIUrl":"10.1016/j.ijggc.2025.104362","url":null,"abstract":"<div><div>Carbon Capture, Utilization, and Storage (CCUS) through CO₂ Enhanced Oil Recovery (CO₂-EOR) supports energy production while reducing atmospheric CO₂ emissions. Economic profitability, not environmental effectiveness, typically drives operators’ decisions. The objective of this paper is to examine the relationship between economic and environmental benefits under various flood designs (continuous CO₂ injection and Water-Alternating-Gas (CO₂-WAG) injection scenarios) and economic conditions, proposing operational and policy solutions to simultaneously optimize both. Net CO₂ emissions and Net Present Value (NPV) serve as indicators of environmental and economic outcomes, respectively. We integrate a reservoir simulation, a life cycle emissions analysis, and an economic model.</div><div>Results show that continuous CO₂ injection maximizes environmental benefits. Without carbon storage incentives, economic and environmental gains are misaligned, with operators favoring practices that maximize net CO₂ emissions. A dynamic breakeven carbon storage incentive, sensitive to oil prices and CO₂ acquisition costs, is essential for alignment. Incentives below breakeven improve economic profitability with limited environmental gains. Operator responsibility for mitigating climate change, along with CO₂ availability, also influences this alignment. Uniform incentive systems, such as the 45Q tax credit system in the U.S., present challenges, often requiring unrealistically high incentives and tying total incentives to the volume of net CO₂ stored, rather than the actual environmental impact. To address these issues, we propose a novel alternative tiered, performance-based metric that directly links incentives to environmental outcomes through storage efficiency, defined as the amount of CO₂ effectively stored after accounting for upstream, gate-to-gate, and downstream emissions per barrel of oil produced.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"143 ","pages":"Article 104362"},"PeriodicalIF":4.6,"publicationDate":"2025-03-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143683618","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Experimental and numerical investigation on near-field temperature and surface CO2 concentrations of buried dense phase CO2 pipeline leakage","authors":"Junpeng Zhang ,&nbsp;Shaodong Jing ,&nbsp;Zhenning Fan ,&nbsp;Haining Liang ,&nbsp;Junhui Zhang ,&nbsp;Yan Zhang ,&nbsp;Chunlong Sun ,&nbsp;Jian Zhang","doi":"10.1016/j.ijggc.2025.104360","DOIUrl":"10.1016/j.ijggc.2025.104360","url":null,"abstract":"<div><div>Once the CO₂ fluid in the buried long-distance dense-phase pipeline leaks, it poses a significant threat to the surrounding environment and the safety of personnel. A large-scale field leakage diffusion test was conducted based on the CCUS million-ton buried dense phase long-distance CO₂ pipeline project in this study. The impact of the leakage's size (2 mm, 3 mm, 4 mm) and direction (horizontal, upward, and downward) on the soil morphology, temperature change, and surface CO₂ concentration around the leakage hole was studied. The velocity, CO₂ concentrations, and temperature field near the leakage port during the leakage process are simulated to supplement the experiments. The findings indicate that soil fissuring occurs when the leakage aperture exceeds 3 mm. The diameter of the frozen soil generated when the diameter of the vertical leakage is 4 mm is approximately twice that of the leakage diameter of 2 mm. Downward leakage has the most significant impact on low-temperature areas and the largest dry ice area under the condition of the same leakage port. The temperature drop rate increased directly to the size of the leakage hole, especially in the region 20–30 cm away from the leakage port. The surface CO₂ concentrations at the monitoring point at a height of 0.4 m above the leakage point for 2 mm leakage are predominantly influenced by wind. A height of 0.8–1.2 m can be selected as the appropriate monitoring height for leakage detection of the buried dense phase CO₂ pipeline. The surface CO₂ concentrations initially increase, subsequently decline and then experience a sudden surge due to the rupture and refreezing of the dry ice layer for leakage with an aperture larger than 3 mm. The horizontal and vertical diffusion distances of CO₂ concentrations up to 5 vol% were 1.5 m and 0.8 m for different direction tests after the rupture of soils. The research findings can provide valuable insights for improving leakage detection systems and performing risk assessments.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"143 ","pages":"Article 104360"},"PeriodicalIF":4.6,"publicationDate":"2025-03-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143683603","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Early-stage risk assessment for the Uinta Basin CarbonSAFE Phase II project","authors":"Ting Xiao ,&nbsp;Jennifer Fitzgibbon ,&nbsp;Michael Vanden Berg","doi":"10.1016/j.ijggc.2025.104359","DOIUrl":"10.1016/j.ijggc.2025.104359","url":null,"abstract":"<div><div>Carbon dioxide (CO₂) capture, utilization, and storage (CCUS) is considered a key solution to mitigate greenhouse gas emissions and limit climate change. Risk assessment and management are essential for CCUS projects. This article presents a case study of the Uinta Basin CarbonSAFE Phase II project to identify and assess potential risks associated with the development of commercial-scale CCUS in the Uinta Basin, eastern Utah, United States (U.S.), by an online questionnaire from six categories: economy, legal/policy, environment, social, management, and technicality. Specifically, 138 features, events, and processes (FEP) are identified and evaluated by feedback from project participants, experts, and residents.</div><div>Financial viability and CCUS legislation/policy are recognized as the highest-ranked risks. These are not unique to the Uinta Basin, but to the U.S. and the world. Updated legislation and policy incentives are expected to drive further development of CCUS, reduce the cost, and achieve climate expectations. Technical concerns include potential faults/fractures and their activation/growth, which require further quantitative assessment. In contrast, job loss is considered as a low risk, indicating potential economic growth with the deployment of CCUS. The results also suggest that preventive and mitigative activities should include technical assistance to operators and stakeholders regarding the most recent CCUS policies and requirements, and training programs for the next generation of the workforce.</div><div>This study provides an example of identifying potential risks at an early stage for CCUS deployment, and the responses of Uinta Basin residents can help establish effective communication channels between the project team and the local community.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"143 ","pages":"Article 104359"},"PeriodicalIF":4.6,"publicationDate":"2025-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143683617","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"High-spatial-resolution slip tendency modeling based on 3D seismic data to assess induced earthquake potential and identify suitable CO2 storage sites","authors":"Daulet Bakhtiyar ,&nbsp;Takeshi Tsuji","doi":"10.1016/j.ijggc.2025.104355","DOIUrl":"10.1016/j.ijggc.2025.104355","url":null,"abstract":"<div><div>We propose a methodology for estimating slip tendency in a target geological setting with high spatial resolution using three-dimensional (3D) seismic reflection data. This framework assesses the potential for fluid-injection-induced earthquakes and identifies suitable well locations for CO₂ injection by integrating seismic interpretation, quantitative slip tendency analysis, and geostatistical modeling. A total of 242 normal and thrust faults extending to the seafloor were manually identified in the 3D seismic volume, with their dips and strikes determined. The stress tensor and slip tendencies for the faults were calculated mainly using fault geometry as input information for stress inversion, followed by geostatistical modeling. The validity of the slip tendency model was evaluated by comparing the modeled slip tendencies with past earthquake hypocenters. Areas of higher slip tendencies exhibited higher seismicity, indicating an increased likelihood of induced earthquakes in these regions. The mean slip tendency near hypocenters is much higher than the overall grid average. Although there are no CO₂ injection site in the study area, we present a case study for identifying suitable CO₂ storage sites within a 3D seismic data volume. The findings highlight the potential of this approach in advancing our understanding of fault behavior and seismicity within a given area, aiding in the assessment of geological hazards and the identification of slip-prone areas relevant to carbon capture and storage and other fluid management projects.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"143 ","pages":"Article 104355"},"PeriodicalIF":4.6,"publicationDate":"2025-03-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143683615","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Optimizing the management of quarry fines for on-site carbon removal: Implications of grain size and mineralogy on CO2 mineralization","authors":"Amanda R. Stubbs ,&nbsp;Faisal W.K. Khudhur ,&nbsp;Ian M. Power ,&nbsp;Linzi McDade ,&nbsp;Mark Friel ,&nbsp;Iain Neill ,&nbsp;John MacDonald","doi":"10.1016/j.ijggc.2025.104344","DOIUrl":"10.1016/j.ijggc.2025.104344","url":null,"abstract":"<div><div>Weathering of basaltic quarry fines can enable quarries to remove CO₂ by optimizing the management of underutilized rock fines. In this study, basaltic fines from two quarries in Scotland are used as potential feedstocks for ERW. Using column experiments, fines from both sites were placed into columns as layers with varying thicknesses (1 cm and 5 cm) and grain sizes (bulk and &lt;100 μm). Fines were saturated (≈60 % pore water) and exposed to ambient UK conditions (10 °C, 0.04 % CO₂) and accelerated carbonation conditions (50 °C, 20 % CO₂). Quarry site 1 experienced negligible increases in TIC within bulk fines under ambient conditions, yet fines &lt;100 μm experienced carbonation equivalent to 440 g CO₂/m²/yr. However, the total inorganic carbon content (TIC) nearly doubled in the bulk fines from quarry site 2 (5 cm) under ambient conditions, equivalent to 570 g CO₂/m²/yr. In the sieved fines from the same site the TIC content nearly tripled, equivalent to 1330 g CO₂/m²/yr. At site 2, if the bulk fines could be deposited over 0.8 km² of land in 5 cm thicknesses, approximately 460 t CO₂/yr could be sequestered with minimal management practices in place. Using fresh fines that have not previously weathered in stockpiles is important for maximizing the carbon dioxide removal potential. Despite higher carbon offsets within the sieved material, the energy and cost required to crush rock from bulk to &lt;100 μm is not economically feasible, as it exceeds the value of carbon which it could be sold for.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"143 ","pages":"Article 104344"},"PeriodicalIF":4.6,"publicationDate":"2025-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143641923","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Spatiotemporal shapley value-based pressure signal decomposition for enhanced geological carbon sequestration monitoring under uncertainty","authors":"Jose L. Hernandez-Mejia ,&nbsp;Michael J. Pyrcz","doi":"10.1016/j.ijggc.2025.104356","DOIUrl":"10.1016/j.ijggc.2025.104356","url":null,"abstract":"<div><div>Geological Carbon Sequestration (GCS) involves capturing CO₂ from anthropogenic sources, such as power plants and industrial processes, and injecting it into geological formations for permanent storage. Monitoring subsurface CO₂ migration is essential to ensure that the injected CO₂ remains safely sequestered and does not leak into the atmosphere. Pressure sensing, in particular, is a cost-effective and efficient method for monitoring large pore networks and detecting changes in subsurface conditions. However, the presence of multiple CO₂ injector wells operating under distinct conditions, such as varying injection rates, well locations, and completion designs, complicates the pressure response observed in monitoring wells. This complexity makes it challenging to accurately track individual CO₂ plumes originating from specific injector wells. Understanding the pressure dynamics is crucial for ensuring the integrity of the storage site and optimizing injection strategies. To address this challenge, this study proposes a comprehensive workflow for bottomhole pressure (BHP) decomposition. We utilize Shapley values, combined with geostatistical modeling and numerical flow simulation, to determine the individual pressure contributions from each injector well to the monitoring wells. By discretizing Shapley values in both time and space for a given subsurface model, we calculate the marginal pressure contributions of injector wells while accounting for interaction effects, spatial context, and time-varying operational conditions. This approach enhances the accuracy and reliability of GCS monitoring. Additionally, partial dependency plots are created to evaluate the pressure dynamics between injectors and monitor BHP over time, providing valuable insights into the behavior of the storage reservoir.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"143 ","pages":"Article 104356"},"PeriodicalIF":4.6,"publicationDate":"2025-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143628263","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Decarbonising the energy sector with oxy-combustion CCS: A techno-economic analysis of the Graz Cycle power plant","authors":"Benjamin Mitterrutzner ,&nbsp;Wolfgang Sanz","doi":"10.1016/j.ijggc.2025.104343","DOIUrl":"10.1016/j.ijggc.2025.104343","url":null,"abstract":"<div><div>The objective of this paper is to assess the economic costs of an oxy-combustion power plant with CO₂ capture, known as the Graz Cycle. For this purpose, we employ a methodology based on common practices in the field of point-source CO₂ capture and storage (CCS) utilising a process modelling tool to analyse the economic cost metrics under (a) full-load and (b) part-load condition. On this basis, we assess (i) the total annualised cost, (ii) the levelised cost of electricity, and (iii) the CO₂ avoidance cost of the Graz Cycle fired with natural gas. The result for a Graz Cycle pilot plant with approximately 62 MW net power output and a natural gas price of 30 €/MWh (base case) show a total annualised cost of 55.6 M€/a and a levelised cost of electricity of 113.3 €/MWh. An investment analysis shows that the Graz Cycle reaches economic break-even at a natural gas price of <span><math><mo>∼</mo></math></span>95 €/MWh. Moreover, the analysis reveals that the Graz Cycle has a cost advantage over natural gas combined cycles with post-combustion capture, particularly in scenarios with high CO₂ taxes and a large installed plant capacity. The main contribution of this paper is a unique techno-economic analysis of the Graz Cycle, demonstrating its efficiency and economic viability across varying operational scenarios and CO₂ tax regimes.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"143 ","pages":"Article 104343"},"PeriodicalIF":4.6,"publicationDate":"2025-03-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143601051","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Regional screening of saline aquifers in the Malay Basin for CO2 storage","authors":"Iain de Jonge-Anderson ,&nbsp;Hariharan Ramachandran ,&nbsp;Ana Widyanita ,&nbsp;Andreas Busch ,&nbsp;Florian Doster ,&nbsp;Uisdean Nicholson","doi":"10.1016/j.ijggc.2025.104347","DOIUrl":"10.1016/j.ijggc.2025.104347","url":null,"abstract":"<div><div>The Malay Basin has received significant attention for geological carbon dioxide storage (GCS), but there are no published studies addressing the selection of appropriate deep saline aquifers. This study closes this gap. We process spatial data and use geological modelling and cluster analysis to identify optimal areas for GCS, considering various subsurface characteristics such as temperature, pressure, porosity and thermophysical CO₂ properties. It is found that the basin contains numerous Cenozoic aquifers suitable for GCS including locally thick, but low net-to-gross (NTG), stacked formations. Pliocene aquifers are too shallow to offer storage for CO₂ in large quantities, but upper Miocene aquifers located in the northwest of the basin contain promising intervals with significant porosities and conditions favouring denser CO₂. Middle Miocene aquifers, while low NTG, are thick, and optimally located around the margins of the basin. They also have significant storage capacity and could be developed as a stacked GCS site. Lower Miocene aquifers are higher NTG, but deeply buried across many areas of the basin, yet the oldest aquifer evaluated still holds substantial storage capacity, where subject to minor burial at the margins of the basin. Overall, this study provides a novel first assessment of aquifer GCS potential in the Malay Basin, while also contributing to wider efforts to evolve screening workflows for other geological basins.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"143 ","pages":"Article 104347"},"PeriodicalIF":4.6,"publicationDate":"2025-03-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143592647","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}