Day 2 Mon, February 20, 2023最新文献

{"title":"Rotating Equipment Switchover Optimization to Enhance Equipment Reliability and Minimize Emissions","authors":"Kinnjalkumar Gohel","doi":"10.2118/213599-ms","DOIUrl":"https://doi.org/10.2118/213599-ms","url":null,"abstract":"\u0000 The association of rotating equipment switchover strategy with machinery health and reliability is discussed. The paper includes the design considerations for spare equipment in processing facilities, need for a switchover strategy, factors affecting the equipment switchover and the benefits of optimizing the switchover strategy in terms of equipment reliability and HSE.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"77 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122933190","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Streamlining Overshot BHA's: A Guideline to Optimize Fishing in Horizontal Wells","authors":"Sulaiman Almansour, Elspeth M. Crawford, Bader Alzahrani, Zahaezuani Rafiq Hamidon","doi":"10.2118/213742-ms","DOIUrl":"https://doi.org/10.2118/213742-ms","url":null,"abstract":"\u0000 While the industry has many recommendations on fishing operations and setups, a process of the selection for overshots, and a streamline when similar fish or wellbore conditions has not been discussed before. This paper will review a challenging case history well, with multiple fishes of the same type, and the lessons learned on selections with varying wellbore conditions. Taking into measure was the learnings from the post well review, and the creation of a flowchart to better optimize the selection of fishing Bottom Hole Assembly's (BHA). This incorporated the coordination of charts’ creation with the service provider, ensured a robust process with multiple choices and supportive reasoning for selection. The well primarily discussed in this paper, was a horizontal well in a tight gas field. The knowledge gained from the multiple fishes in the case study horizontal well, streamlined future choices in BHA selections for similar fishes. As an operator, having the flowchart encourages more discussion with the service company, and supports the engineers in planning operations.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"4 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126327032","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Optimizing the Hydraulic Fracturing Fluid Systems Using the Completion and Production Data in Bakken Shale","authors":"Najd Alotaibi, Serkan Dursun","doi":"10.2118/213360-ms","DOIUrl":"https://doi.org/10.2118/213360-ms","url":null,"abstract":"\u0000 Objectives/Scope. Well completion is an important step for every well to undergo in order to prepare it for oil and gas extraction. Based on the nature and characteristics of an oil and gas reservoir, appropriate well completion practices are selected to enhance the production. Hydraulic fracturing is one such technique. It frequently involves horizontal drilling and injecting fluids under high pressure to fracture the rock. The larger fractures along with the injected fluid enable high amounts of trapped natural gas and crude oil to flow out of the formation to the producing well bore. In well completion, a variety of chemicals are employed to leverage oil production, and the goal of this study is to determine how such chemicals impact performance rate in several unconventional wells in the Bakken Shale.\u0000 Methods, Procedures, Process. In this approach, two Completion and Production datasets from North Dakota (the Bakken Shale) and fracFocus were processed and combined accordingly which resulted in some of the following parameters, type of chemical and amount of chemical, and true vertical depth of the wells. And the dataset that was produced was analyzed based on the stimulation treatment. The proposed workflow utilizes supervised machine learning algorithms to train different predictive models to estimate the amount of the produced oil; including but not limited to neural Random Forest, CATboost and XGboost. Additionally, by quantifying each chemicals’ importance on oil production, this investigation was able to determine each chemical's influence.\u0000 Results, Observations, Conclusions. This study examined the impact of more than 2500 different completion chemicals on the oil production of unconventional reservoir and discovered the chemicals with the highest significance on the oil production, given that, the predictive models were able to estimate the oil production accurately after feeding it with the type and measures of the most influencing chemicals.\u0000 Novel/Additive Information. The most important pillar of this framework is that it expedites the workflow of hydraulic fracturing jobs in the unconventional reservoir by providing an accurate model that optimizes its parameters to maximize the oil production rate. This solution offers an automated decision-making process for the selection of chemical types to be used in the hydraulic fracking jobs. The choice of chemicals in fracturing fluids is affected by many variables, including its compatibility with the target rock formation to be hydraulically fractured, the geology of the rock formations being drilled through, the pressure and temperature measurements in the target formation, cost, operator preference, and possible interactions between chemicals in the treatment fluid.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"15 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124671215","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"CO2 Huff-n-Puff: An Experimental and Modeling Approach to Delineate Mass Transfer and Recovery from Shale Cores","authors":"S. Alahmari, M. Raslan, Pooya Khodaparast, Anuj Gupta, Jewel Duncan, Stacey M Althaus, K. Jessen","doi":"10.2118/213400-ms","DOIUrl":"https://doi.org/10.2118/213400-ms","url":null,"abstract":"\u0000 Gas injection has been demonstrated to be an effective approach to enhance recovery from ultra-tight fractured reservoirs where the role of molecular diffusion often becomes dominant. The open literature offers a large collection of work concerned with gas injection studies and projects, employing carbon dioxide (CO2), methane (CH4) and other gases, and reports a considerable improvement in oil recovery over primary production. CO2 injection has an additional advantage over other gases through the potential for geological sequestration. This explains the growing interest in studying diffusive mass transfer during CO2 injection to delineate the sequestration potential in concert with enhanced oil recovery from unconventional resources. However, additional work is needed to arrive at a comprehensive understanding and representation of diffusive mass transfer in ultra-tight fractured formations.\u0000 In this paper, we study diffusive mass transfer in shale cores by conducting and simulating CO2 Huff-n-Puff (HnP) experiments at high pressure and temperature. Two cores from a formation in the Middle East were evacuated and then saturated at 3500 psi and 50°C with a synthetic oil consisting of decane (nC10), dodecane (nC12), tetradecane (nC14) and hexadecane (nC16). We performed multiple HnP cycles at varying injection conditions: 2900-4000 psi and 70 °C. Diffusive mass transfer was then investigated via (1) evaluating the effect of injection pressure on oil recovery, (2) analyzing produced oil compositions, and (3) studying the pressure decline during the soaking period.\u0000 Our experimental observations show that a higher oil recovery is achieved when injecting at a higher pressure. We also observe that molecular diffusion acts as a dominant recovery mechanism in the HnP experiments, as evident from analyzing the produced oil composition and from examining the pressure behavior versus time during the soaking periods: The observed decline rate in the pressure during soaking signify that molecular diffusion dictates the mass transfer during the HnP experiments. Additionally, we note that miscibility conditions will change from one HnP cycle to another, as the injected gas mixes with an oil composition that changes between cycles.\u0000 We have used the CMG-GEM compositional simulator to interpret the HnP experimental results. When multicomponent diffusion coefficients were computed using the correlation of Sigmund (1976) the simulator is unable to provide a reasonable prediction of oil recovery and produced oil compositions. To achieve a better prediction of diffusive mass transfer in ultra-tight fractured reservoirs, a representation that is based on a more fundamental description of the multicomponent diffusion coefficients is hence required, as discussed in-depth by Alahmari and Jessen (2021) and Shi et. al. (2022).","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"16 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121847320","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Successful Testing and Sampling the Desired Formation Fluids Despite the Challenging Environment in the Middle East","authors":"I. B. Espinoza, R. Perdigón, H. Osunluk, Kashif Mushir Khan","doi":"10.2118/213467-ms","DOIUrl":"https://doi.org/10.2118/213467-ms","url":null,"abstract":"\u0000 Most of the time a brownfield's formation producibility is no surprise to petrophysicists and reservoir engineers, however, the downhole conditions change continuously in the oil and gas production and injection. Therefore, it is critical to acquire high-quality representative testing and sampling data in real-time despite formation uncertainties and operation constraints.\u0000 There are several challenges when acquiring the wireline formation testing (WFT) and sampling services in Middle East. The downhole real time fluid properties must be representative of reservoir conditions and provide fluid fractions, water salinity, contamination, etc. At the same time, there is a big constraint on the operational time limit per station due to the substantial risk of getting stuck. In complex lithologies, it is critical to understand the fluid's connectivity between layers and rock compressive strengths as the expectations may not match reality. To meet the abovementioned challenges the WFT technologies must be equipped operationally and provide a valid instantaneous interpretation.\u0000 Current research covered cases across several countries in the Middle East. In low-mobility formation the challenge was on operational ability to continuously pump-out for extended hours. The record-breaking results were achieved with 36 hours of pumping-out, with bubble point as close as 50 psi below formation pressure. Some advanced features were implemented including FT pre-job modeling and real-time support vertical interference tests, which helped to complete the injector well as planned. Many challenges comes in differentiation between formation and filtrate water in real-time. It was solved using the only resistivity sensors available in current WFT setup. For deep tight gas reservoirs, the sampling in tight environment were an issue, nevertheless, getting a single sweet spot allowed to collect representative gas samples. Dealing with retrograde condensate field might be tricky when the condensate precipitation and gas appearance are not known. In presented cases the two scenarios shows the appearance of gas across the zone and appearance of condensate. The results were compared to production logging (PLT) to clarify the unusual multi-phase changes in phase behavior.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"43 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121524511","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Unleashing the Full Geothermal Potential of Türkiye Through Collaboration and Learning from the Oil & Gas Industry","authors":"Selin Pedrosa, O. Ochoa, S. Erdurmus, H. Oueslati, M. Siyako, E. Damcı","doi":"10.2118/213241-ms","DOIUrl":"https://doi.org/10.2118/213241-ms","url":null,"abstract":"\u0000 Developing of enhanced geothermal systems will be critical for future energy markets and successful energy decarbonization. New technologies and holistic drilling approaches will allow access to previously untapped sources and ensure projects are economically viable. Türkiye is the world's fourth largest geothermal energy producer with 1700 MWe of installed power capacity after the USA, Indonesia, and the Philippines. The Anatolian plate, which Türkiye is situated on, is located on the Alpine-Himalayan orogenic belt making the region one of the most seismically active places in the world. Due to these and other conditions, the country has a significant potential for geothermal energy production.\u0000 Since 2010, there has been a strong collaboration between service companies and geothermal operators to provide advanced directional drilling services in the geothermal market. This successful collaboration enabled operators to drill deeper, higher temperature geothermal wells for electricity production and provided significant environmental and economic development for different fields. Typical drilling conditions for these applications are harsh and the static temperature ranges between 220°C to 295 °C. The depth of the wells varies between 2500 m-4800 m depending on the reservoir, within high temperatures and harsh drilling conditions.\u0000 In this paper, the authors discuss the challenges of directional drilling in Türkiye's geothermal fields, and how the best practices and innovations established from the Oil & Gas industry were successfully adopted into this specific energy market, including the deployment of sophisticated Rotary Steerable Systems (RSS).","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"15 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121094106","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Using Tracer-Based Technologies for Production Profiling in a Hydraulic Fracture to Optimise the Hydraulic Fracturing Design","authors":"Vishwajit Upadhye, E. Malyavko, D. Kashapov","doi":"10.2118/213270-ms","DOIUrl":"https://doi.org/10.2118/213270-ms","url":null,"abstract":"\u0000 The tracer-based surveillance technology can be used in hydraulic fractures to perform production profiling surveillance continuously for several years without the need for expensive and operationally risky interventions. The paper deals with the case of placing tracer coated marked proppant with different signatures in each hydraulic fracturing stage. In particular, it dwells on the experience of placing different signatures of tracer coated marked proppant within one port to evaluate the production dynamics of the far and near zones of a hydraulic fracture. The paper also offers methods for optimizing the hydraulic fracturing design to increase the hydraulic fracture production period and the cumulative production.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"32 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"117201990","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Hydraulic Fracturing of Highly Azimuthally-Deviated Horizontal Wells Enhanced by Wellbore Notching","authors":"M. AlTammar, K. Alruwaili, H. Al-Dakheel, G. Aidagulov, M. Abbad","doi":"10.2118/213309-ms","DOIUrl":"https://doi.org/10.2118/213309-ms","url":null,"abstract":"\u0000 Multistage hydraulic fracturing is an effective stimulation method as it opens communication between the wellbore and larger reservoir volumes. Nevertheless, there are cases where the formation cannot be fractured within the completion pressure limitations. This problem can be addressed by placing weak points, such as perforations and notches, so fractures could initiate there at lower pressure. This paper discusses this remedy applied in horizontal open holes that are highly deviated from the minimum horizontal stress.\u0000 In this study, cement grout block samples (24×18×18 in.) were prepared to cast precisely weak points and boreholes. The cured blocks were completed with 1.25×12 in. (diameter × length) long openhole section in the center. Hydraulic fracturing experiments were conducted inside a polyaxial load-frame to simulate the wellbore under strike-slip stress regime. Boreholes of two azimuthal deviations from minimum stress were considered: 0° (straight) and 35° (inclined). For each, two weak points were tested: V-notch and single perforation. Fracturing fluid was injected at low rate into the borehole. The obtained injection pressure trends were interpreted with open holes cored out to analyze the initiated fractures.\u0000 Both fracture initiation pressure (FIP) and fracture breakdown pressure (FBP) (i.e., the maximum) were selected for comparisons, as the former is not influenced by the fracture size nor by the fluid-rock interactions during propagation. FIP was estimated indirectly as deviation from linearity in the borehole injection pressure trend. The results revealed remarkably that the notch significantly reduces FIP and FBP, compared with the reduction by the single perforation, in both the straight and inclined boreholes. Each of the weak points delivered very similar FIP and FBP in straight and inclined boreholes. All the weak points initiated a fracture that is transverse to the borehole axis, which provides the advantage of 360° communication with the reservoir. It was noticed that the inclined borehole with one perforation initiated a transverse fracture with a distinct angle from the preferred plane. To summarize, even if the wellbore is drilled at a high angle of deviation from the minimum horizontal stress in the strike-slip regime, the notch still outperforms perforation in terms of FIP reduction.\u0000 This work presents experimental comparisons of hydraulic fracturing pressure reductions caused by notches and single perforation holes placed in horizontal open holes aligned with and highly deviated from the minimum horizontal stress. The experiments showed how notches outperform conventional perforation, and by this, provide insights for stimulation design of horizontal wells where trajectories were influenced by factors other than stimulation, such as geology and reservoir location.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"28 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114946351","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Frac Plug Evaluation to Improve Operations Efficiency","authors":"S. Baki, Abdullah Alzamil, Zeyad Habiballah, Emad Shariff, Abdulrahman Alowaid, Wafaa Alnakhli, H. Alshammari, Mohannad Mahfouz","doi":"10.2118/213262-ms","DOIUrl":"https://doi.org/10.2118/213262-ms","url":null,"abstract":"\u0000 Success of the unconventional resources (UR) operations is improving the efficiency by minimizing cost without compromising production. Plug and perforation (PnP) method is widely applied practice for unconventional wells completion due to flexibility of stimulating targeted intervals. One of the key parameters for operations efficiency of stimulation activities is utilization of fit for purpose frac plug to run with wireline PnP, proper frac isolation, and increasing efficiency of coil tubing mill-out. This paper provides comprehensive evaluation and comparison of various frac plug selection, execution and evaluation as well as optimization considering improving efficiency at multi-stage frac operations.\u0000 To improve contact area with targeted formations, longer laterals are drilled and during milling operations, it can generate additional challenges to the milling efficiency due to decreasing weight on bit and potential lockups due extended laterals. There are various types of plugs in the market depending on the technical requirements of the operation such as composite, semi-dissolvable and fully dissolvable fracturing plugs. Therefore, the search to obtain the most optimum fit for purpose frac plug selection is critical with the objective of being milled with minimal weight on bit and low to no debris produced from milling activities. The application of a rigorous system for choosing frac plugs to be tested and implemented considers various well completion, formation, operational and technical parameters, while cross-referencing case studies and historical usage at different fields worldwide.\u0000 For the current study, more than twenty frac plugs were systematically evaluated based on technical requirements, and were implemented across more than 2,000 stages of UR stimulation applications and coil tubing (CT) millout operations. Additionally, the paper discusses about contingency plans with solutions during wireline pump down and coil tubing millout operations challenges and opportunities.\u0000 Fracturing plug manufacturers are continuously improving their frac plug technologies to meet customers demands of ease of use, applicability and functionality. Hence, the introduction and development of semi or fully dissolvable plugs. This paper highlights a full cycle of process for qualifying fracturing plugs for fit-for-purpose applications.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"29 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129579110","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Sulfate Ion Removal from Seawater for Hydraulic Fracturing by Barium Sulfate Precipitation","authors":"J. Hou, Fahd I. Alghunaimi, M. Han, Norah W. Aljuryyed","doi":"10.2118/213227-ms","DOIUrl":"https://doi.org/10.2118/213227-ms","url":null,"abstract":"\u0000 To face the worldwide shortage of fresh water resources and the increase demand of oil and gas, researchers have devoted to study on application of seawater as a base fluid for hydraulic fracturing. One of the primary challenges for seawater fracturing application is the scale precipitation tendency due to the incompatibility of high sulfate concentration with high calcium, barium or strontium concentration in formation water, which will lead to overall reduction in production capacity. This work aims to develop a chemical precipitation method, which is a low cost way to remove sulfate before injection to solve the scale problem.\u0000 Barium chloride dihydrate was used to precipitate sulfate from seawater for hydraulic fracturing. The chemical dosage, working temperature and precipitation time were optimized. The sulfate concentration in treated water was determined using an inductively coupled plasma mass spectrometer (ICP-MS). The sedimentation speed to separate treated water and precipitates at different precipitation time was measured using an optical particle stability analyzer. The obtained precipitates were dried at 60?C, and the morphology was observed using scanning electron microscopy (SEM) and X-ray diffraction method (XRD).\u0000 Experimental results showed the barium chloride dihydrate can reduce the sulfate concentration in seawater from more than 4,000 ppm to less than 200 ppm when the dosage barium is higher than 5,500 ppm. The reaction efficiency is not altered in the temperature range from 15ºC to 45ºC. It turned out the treated seawater could meet the requirement for hydraulic fracturing application. As to the separation of water and precipitates using sedimentation method, it showed the highest speed appeared when precipitation time was 5 mins. And the addition of flocculants cannot improve the sedimentation speed. In addition, SEM results showed the size of obtained precipitates was in nanometer range. Besides, XRD confirmed the composition of precipitates were barium sulfate with purity >90%. The characterization results demonstrated the precipitates could be used as additives in drilling fluid, which will greatly reduce the operation cost.\u0000 The work has revealed that barium sulfate precipitation method is promising to remove sulfate in seawater for hydraulic fracturing. Besides, the obtained barium sulfate is a commercially valuable product used in drilling fluid. Comparing to nanofiltration methods, this method is low cost and has no energy input requirement, which is suitable for a low carbon economy.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"48 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129190852","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}