Pub Date : 2024-10-01DOI: 10.1016/j.petsci.2024.06.001
Fracturing operations can effectively improve the production of low-permeable reservoirs. The performance of fracturing fluids directly affects the fracturing efficiency and back flow capacity. As polymer-based fracturing fluids (such as guar gum (GG), polyacrylamide (HPAM), etc.) are high-viscosity fluids formed by viscosifiers and crosslinking agents, the degree of gel breakage after the fracturing operation directly influences the damage degree to the reservoir matrix and the mobility of oil angd gas produced from the reservoir into the wellbore. This study compared the viscosity, molecular weight, and particle size of the fracturing fluid after gel breakage prepared by GG and HPAM as viscosifiers, as well as evaluate their damage to the core. Results show that the viscosities of the gel-breaking fluid increased with the concentration of the viscosifier for both the HPAM-based and GG-based fracturing fluids. For the breaking fluid with the same viscosity, the molecular weight in the HPAM-based gel-breaking fluid was much larger than that in the GG-based system. Moreover, for the gel-breaking fluid with the same viscosity, the molecular particle size of the residual polymers in the HPAM-based system was smaller than that in the GG-based system. The damage to the core with the permeability of 1 × 10−3 μm2 caused by both the HPAM-based and GG-based gel-breaking fluids decreased with the increase in the solution viscosity. For the gel-breaking fluid systems with the same viscosity (i.e., 2–4 mPa s), the damage of HPAM-based fracturing fluid to low-permeability cores was greater than the GG-based fracturing fluid (45.6%–80.2%) since it had a smaller molecular particle size, ranging from 66.2% to 77.0%. This paper proposed that the damage caused by hydraulic fracturing in rock cores was related to the partilce size of residual polymers in gel-breaking solution, rather than its molecular weight. It was helpful for screening and optimizing viscosifiers used in hydraulic fracturing process.
{"title":"Experimental study of reservoir damage of water-based fracturing fluids prepared by different polymers","authors":"","doi":"10.1016/j.petsci.2024.06.001","DOIUrl":"10.1016/j.petsci.2024.06.001","url":null,"abstract":"<div><div>Fracturing operations can effectively improve the production of low-permeable reservoirs. The performance of fracturing fluids directly affects the fracturing efficiency and back flow capacity. As polymer-based fracturing fluids (such as guar gum (GG), polyacrylamide (HPAM), etc.) are high-viscosity fluids formed by viscosifiers and crosslinking agents, the degree of gel breakage after the fracturing operation directly influences the damage degree to the reservoir matrix and the mobility of oil angd gas produced from the reservoir into the wellbore. This study compared the viscosity, molecular weight, and particle size of the fracturing fluid after gel breakage prepared by GG and HPAM as viscosifiers, as well as evaluate their damage to the core. Results show that the viscosities of the gel-breaking fluid increased with the concentration of the viscosifier for both the HPAM-based and GG-based fracturing fluids. For the breaking fluid with the same viscosity, the molecular weight in the HPAM-based gel-breaking fluid was much larger than that in the GG-based system. Moreover, for the gel-breaking fluid with the same viscosity, the molecular particle size of the residual polymers in the HPAM-based system was smaller than that in the GG-based system. The damage to the core with the permeability of 1 × 10<sup>−3</sup> μm<sup>2</sup> caused by both the HPAM-based and GG-based gel-breaking fluids decreased with the increase in the solution viscosity. For the gel-breaking fluid systems with the same viscosity (i.e., 2–4 mPa s), the damage of HPAM-based fracturing fluid to low-permeability cores was greater than the GG-based fracturing fluid (45.6%–80.2%) since it had a smaller molecular particle size, ranging from 66.2% to 77.0%. This paper proposed that the damage caused by hydraulic fracturing in rock cores was related to the partilce size of residual polymers in gel-breaking solution, rather than its molecular weight. It was helpful for screening and optimizing viscosifiers used in hydraulic fracturing process.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"21 5","pages":"Pages 3298-3306"},"PeriodicalIF":6.0,"publicationDate":"2024-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"141276336","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2024-10-01DOI: 10.1016/j.petsci.2024.03.004
Developing a green economy is key to achieving the 2030 Sustainable Development Goals. This paper uses the SBM-GML index, which includes non-desired outputs, to measure the trend of regional green economic efficiency changes and analyze the impact mechanism and realization path of industrial transformation on green economic efficiency. The research results show that advanced industrial structure has a positive influence on green economic efficiency nationwide, while energy utilization structure and energy utilization efficiency have positive partial intermediary effects in the influence path; industrial structure rationalization is also significantly positively related to green economic efficiency nationwide, and the mediating effect of energy utilization is positive. The impact of industrial transformation on green economic efficiency has regional heterogeneity, and the mediating effect of energy use also differs. Among them, the impact effect in the eastern region is basically consistent with the national sample, but is negative in the central and western regions. This paper proposes countermeasures in terms of adjusting the industrial structure, improving energy efficiency, and perfecting industrial and energy policies, which can provide theoretical and practical references for promoting the transformation and upgrading of regional industrial structure, optimizing energy utilization, and advancing the efficiency of the national and regional green economy.
{"title":"The impact of industrial transformation on green economic efficiency: New evidence based on energy use","authors":"","doi":"10.1016/j.petsci.2024.03.004","DOIUrl":"10.1016/j.petsci.2024.03.004","url":null,"abstract":"<div><div>Developing a green economy is key to achieving the 2030 Sustainable Development Goals. This paper uses the SBM-GML index, which includes non-desired outputs, to measure the trend of regional green economic efficiency changes and analyze the impact mechanism and realization path of industrial transformation on green economic efficiency. The research results show that advanced industrial structure has a positive influence on green economic efficiency nationwide, while energy utilization structure and energy utilization efficiency have positive partial intermediary effects in the influence path; industrial structure rationalization is also significantly positively related to green economic efficiency nationwide, and the mediating effect of energy utilization is positive. The impact of industrial transformation on green economic efficiency has regional heterogeneity, and the mediating effect of energy use also differs. Among them, the impact effect in the eastern region is basically consistent with the national sample, but is negative in the central and western regions. This paper proposes countermeasures in terms of adjusting the industrial structure, improving energy efficiency, and perfecting industrial and energy policies, which can provide theoretical and practical references for promoting the transformation and upgrading of regional industrial structure, optimizing energy utilization, and advancing the efficiency of the national and regional green economy.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"21 5","pages":"Pages 3644-3655"},"PeriodicalIF":6.0,"publicationDate":"2024-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140268703","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
A series of spontaneous imbibition (SI) tests of tight oil were performed, together with oil distribution scans by computed tomography (CT) and nuclear magnetic resonance (NMR). Thus, the best surfactants to optimize the SI effect were obtained, the basic requirements to surfactants for efficient SI were determined, and the oil mobilization by SI revealed. The results show that anionic surfactants significantly outperform non-ionic, cationic, and zwitterionic ones in SI process. Excellent systems can be further obtained by mixing anionic surfactants with others (e.g. 1:1 mixtures of AES:EHSB). The requirements to interfacial properties of surfactants for achieving efficient SI at permeabilities of 0.05, 0.5, and 5.0 mD are: 10 mN/m, < 40°; 10–10 mN/m, < 55°; and 10–10 mN/m, < 70°, respectively. Although a high oil recovery of 38.5% by SI was achieved in small cylindrical cores (2.5 cm × 3.0 cm), the joint SI and CT tests in larger, cube-shaped cores (5.0 cm × 5.0 cm × 5.0 cm) showed that the SI process could only remove the oil from the outermost few millimeters of the cores with permeabilities of 0.05 and 0.1 mD, indicating the great difficulty encountered for their development. The NMR showed that the SI treatment preferentially removed oil from smaller pores rather than medium or large pores.
对致密油进行了一系列自发浸润（SI）试验，并通过计算机断层扫描（CT）和核磁共振（NMR）对油分布进行了扫描。因此，获得了优化 SI 效果的最佳表面活性剂，确定了高效 SI 对表面活性剂的基本要求，并揭示了 SI 的石油动用情况。结果表明，阴离子表面活性剂在 SI 过程中的表现明显优于非离子、阳离子和齐聚物表面活性剂。通过将阴离子表面活性剂与其他表面活性剂混合（如 AES:EHSB 的 1:1 混合物），可进一步获得优异的体系。在渗透率为 0.05、0.5 和 5.0 mD 时，要实现高效的 SI，对表面活性剂界面特性的要求如下：分别为 10 mN/m，< 40°；10-10 mN/m，< 55°；10-10 mN/m，< 70°。虽然在小型圆柱形岩芯（2.5 厘米 × 3.0 厘米）中，SI 工艺的石油采收率高达 38.5%，但在大型立方体岩芯（5.0 厘米 × 5.0 厘米 × 5.0 厘米）中进行的 SI 和 CT 联合试验表明，SI 工艺只能清除渗透率为 0.05 和 0.1 mD 的岩芯最外层几毫米的石油，这表明其开发遇到了很大困难。核磁共振显示，SI 处理更倾向于清除较小孔隙中的油，而不是中孔或大孔隙中的油。
{"title":"Mobilization of tight oil by spontaneous imbibition of surfactants","authors":"Ming-Chen Ding, Xin-Fang Xue, Ye-Fei Wang, Chu-Han Zhang, Shi-Ze Qiu","doi":"10.1016/j.petsci.2024.08.010","DOIUrl":"https://doi.org/10.1016/j.petsci.2024.08.010","url":null,"abstract":"A series of spontaneous imbibition (SI) tests of tight oil were performed, together with oil distribution scans by computed tomography (CT) and nuclear magnetic resonance (NMR). Thus, the best surfactants to optimize the SI effect were obtained, the basic requirements to surfactants for efficient SI were determined, and the oil mobilization by SI revealed. The results show that anionic surfactants significantly outperform non-ionic, cationic, and zwitterionic ones in SI process. Excellent systems can be further obtained by mixing anionic surfactants with others (e.g. 1:1 mixtures of AES:EHSB). The requirements to interfacial properties of surfactants for achieving efficient SI at permeabilities of 0.05, 0.5, and 5.0 mD are: 10 mN/m, < 40°; 10–10 mN/m, < 55°; and 10–10 mN/m, < 70°, respectively. Although a high oil recovery of 38.5% by SI was achieved in small cylindrical cores (2.5 cm × 3.0 cm), the joint SI and CT tests in larger, cube-shaped cores (5.0 cm × 5.0 cm × 5.0 cm) showed that the SI process could only remove the oil from the outermost few millimeters of the cores with permeabilities of 0.05 and 0.1 mD, indicating the great difficulty encountered for their development. The NMR showed that the SI treatment preferentially removed oil from smaller pores rather than medium or large pores.","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"65 1","pages":""},"PeriodicalIF":5.6,"publicationDate":"2024-08-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142268570","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2024-08-21DOI: 10.1016/j.petsci.2024.08.003
Yu-Shi Zou, Can Yang, Shi-Cheng Zhang, Xin-Fang Ma, Yan-Chao Li, Long-Qing Zou
Temporary plugging and diverting fracturing (TPDF), involving inner-fracture temporary plugging (IFTP) and inner-stage temporary plugging (ISTP), has been proposed as a widely applied technique in China, for promoting the uniform initiation and propagation of multi-clustered hydraulic fractures (HFs) in a horizontal well of the shale oil/gas reservoirs. However, how the key plugging parameters controlling the multi-fracture growth and the pumping pressure response during TPDF in shale with dense bedding planes (BPs) and natural fractures (NFs) is still unclear, which limits the optimization of TPDF scheme. In this paper, a series of TPDF simulation experiments within a stage of multi-cluster in a horizontal well were carried out on outcrops of Longmaxi Formation shale using a large-scale true tri-axial fracturing simulation system, combined with the acoustic emission (AE) monitor and computed tomography (CT) scanning techniques. Each experiment was divided into three stages, including the conventional fracturing (CF), IFTP and ISTP. Multi-fracture initiation and propagation behavior, and the dominant controlling parameters were examined, containing the particle sizes, concentration of temporary plugging agent (TPA), and cluster number. The results showed that the number of transverse HFs (THFs) and the overall complexity of fracture morphology increase with the increase in TPA concentration and perforation cluster number. Obviously, the required concentration of TPA is positively correlated with the cluster number. Higher peak values and continuous fluctuations of pumping pressure during TPDF may indicate the creation of diversion fractures. The creation of standard THFs during CF is favorable to the creation of diversion fractures during TPDF. Moreover, the activation of BPs nearby the wellbore during CF is unfavorable to the subsequent pressure buildup during TPDF, resulting in poor plugging and diverting effect. Notably, under the strike-slip fault stress regime, the diversion of THFs is not likely during IFTP, which is similar as the results of ISTP to initiate mainly the un-initiated or under-propagated perforation clusters. Three typical pressure curve types during TPDF can be summarized to briefly identify the hydraulic fracture diversion effects, including good (multiple branches or/and THFs can be newly created), fair (HF initiation along the slightly opened BPs and then activating the NFs), and bad (HF initiation along the largely opened BPs and then connecting with the NFs).
{"title":"Multi-fracture growth behavior during TPDF in a horizontal well of multi-clustered perforations: An experimental research","authors":"Yu-Shi Zou, Can Yang, Shi-Cheng Zhang, Xin-Fang Ma, Yan-Chao Li, Long-Qing Zou","doi":"10.1016/j.petsci.2024.08.003","DOIUrl":"https://doi.org/10.1016/j.petsci.2024.08.003","url":null,"abstract":"Temporary plugging and diverting fracturing (TPDF), involving inner-fracture temporary plugging (IFTP) and inner-stage temporary plugging (ISTP), has been proposed as a widely applied technique in China, for promoting the uniform initiation and propagation of multi-clustered hydraulic fractures (HFs) in a horizontal well of the shale oil/gas reservoirs. However, how the key plugging parameters controlling the multi-fracture growth and the pumping pressure response during TPDF in shale with dense bedding planes (BPs) and natural fractures (NFs) is still unclear, which limits the optimization of TPDF scheme. In this paper, a series of TPDF simulation experiments within a stage of multi-cluster in a horizontal well were carried out on outcrops of Longmaxi Formation shale using a large-scale true tri-axial fracturing simulation system, combined with the acoustic emission (AE) monitor and computed tomography (CT) scanning techniques. Each experiment was divided into three stages, including the conventional fracturing (CF), IFTP and ISTP. Multi-fracture initiation and propagation behavior, and the dominant controlling parameters were examined, containing the particle sizes, concentration of temporary plugging agent (TPA), and cluster number. The results showed that the number of transverse HFs (THFs) and the overall complexity of fracture morphology increase with the increase in TPA concentration and perforation cluster number. Obviously, the required concentration of TPA is positively correlated with the cluster number. Higher peak values and continuous fluctuations of pumping pressure during TPDF may indicate the creation of diversion fractures. The creation of standard THFs during CF is favorable to the creation of diversion fractures during TPDF. Moreover, the activation of BPs nearby the wellbore during CF is unfavorable to the subsequent pressure buildup during TPDF, resulting in poor plugging and diverting effect. Notably, under the strike-slip fault stress regime, the diversion of THFs is not likely during IFTP, which is similar as the results of ISTP to initiate mainly the un-initiated or under-propagated perforation clusters. Three typical pressure curve types during TPDF can be summarized to briefly identify the hydraulic fracture diversion effects, including good (multiple branches or/and THFs can be newly created), fair (HF initiation along the slightly opened BPs and then activating the NFs), and bad (HF initiation along the largely opened BPs and then connecting with the NFs).","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"25 1","pages":""},"PeriodicalIF":5.6,"publicationDate":"2024-08-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142252609","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
The glutenite reservoir is strongly heterogeneous due to the random distribution of gravels, making it challenging to perform hydraulic fracturing effectively. To solve this issue, it is essential to study interaction behavior between hydraulic fractures (HFs) and gravels. A coupled hydro-mechanical model is proposed for HF propagation in glutenite using a grain-based discrete element method. This paper first investigates the dynamic evolution of HFs in glutenite, then analyzes the influences of various factors such as horizontal stress difference (Δ), minimum horizontal stress (), gravel content (), gravel size (), and stiffness ratio of gravel to matrix () on HF propagation geometries. Results show that penetrating the gravel is the primary HF-gravel interaction behavior, which follows sequential and staggered initiation modes. Bypassing the gravel is the secondary behavior, which obeys the sequential initiation mode and occurs when the orientation of the gravel boundary is inclined to the maximum horizontal stress (). An offset along the gravel boundary is usually formed while penetrating gravels, and the offsets may cause fracture widths to decrease by 37.8%–84.4%. Even if stress dominates the direction of HF propagation, HFs still tend to deflect within gravels. The deviation angle from decreases with rising Δ and increases with the increase of and . Additionally, intra-gravel shear HFs (IGS-HFs) are prone to be generated in coarse-grained glutenite under high Δ, while more gravel-bypassing shear HFs (GBS-HFs) tend to be created in argillaceous glutenite with high than in sandy glutenite with low . The findings above prompt the emergence of a novel HF propagation pattern in glutenite, which helps to understand the real HF geometries and to provide theoretical guidance for treatments in the field.
{"title":"Investigation of interaction behavior between hydraulic fractures and gravels in heterogeneous glutenite using a grain-based discrete element method","authors":"Zhao-Peng Zhang, Yu-Shi Zou, Hai-Yan Zhu, Shi-Cheng Zhang","doi":"10.1016/j.petsci.2024.08.004","DOIUrl":"https://doi.org/10.1016/j.petsci.2024.08.004","url":null,"abstract":"The glutenite reservoir is strongly heterogeneous due to the random distribution of gravels, making it challenging to perform hydraulic fracturing effectively. To solve this issue, it is essential to study interaction behavior between hydraulic fractures (HFs) and gravels. A coupled hydro-mechanical model is proposed for HF propagation in glutenite using a grain-based discrete element method. This paper first investigates the dynamic evolution of HFs in glutenite, then analyzes the influences of various factors such as horizontal stress difference (Δ), minimum horizontal stress (), gravel content (), gravel size (), and stiffness ratio of gravel to matrix () on HF propagation geometries. Results show that penetrating the gravel is the primary HF-gravel interaction behavior, which follows sequential and staggered initiation modes. Bypassing the gravel is the secondary behavior, which obeys the sequential initiation mode and occurs when the orientation of the gravel boundary is inclined to the maximum horizontal stress (). An offset along the gravel boundary is usually formed while penetrating gravels, and the offsets may cause fracture widths to decrease by 37.8%–84.4%. Even if stress dominates the direction of HF propagation, HFs still tend to deflect within gravels. The deviation angle from decreases with rising Δ and increases with the increase of and . Additionally, intra-gravel shear HFs (IGS-HFs) are prone to be generated in coarse-grained glutenite under high Δ, while more gravel-bypassing shear HFs (GBS-HFs) tend to be created in argillaceous glutenite with high than in sandy glutenite with low . The findings above prompt the emergence of a novel HF propagation pattern in glutenite, which helps to understand the real HF geometries and to provide theoretical guidance for treatments in the field.","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"106 1","pages":""},"PeriodicalIF":5.6,"publicationDate":"2024-08-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142268573","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2024-08-07DOI: 10.1016/j.petsci.2024.07.029
Hui-Ying Tang, Ge He, Ying-Ying Ni, Da Huo, Yu-Long Zhao, Liang Xue, Lie-Hui Zhang
The shale revolution has turned the United States from an oil importer into an oil exporter. The success of shale oil production in the U.S. has inspired many countries, including China, to begin the exploitation and development of shale oil resources. In this study, the production curves of over 30,000 shale oil wells in the Bakken, Eagle Ford (EF), and Permian are systematically analyzed to provide reference and guidance for future shale oil development. To find out the most suitable decline curve models for shale oil wells, fifteen models and a new fitting method are tested on wells with production history over 6 years. Interestingly, all basins show similar results despite of their varieties in geological conditions: stretched exponential production decline (SEPD) + Arps model provides most accurate prediction of estimated ultimate recovery (EUR) for wells with over 2 years' production, while the Arps model can be used before the two years’ switch point. With the EUR calculated by decline curve analysis, we further construct simple regression models for different basins to predict the EUR quickly and early. This work helps us better understand the production of shale oil wells, as well as provide important suggestions for the choices of models for shale oil production prediction.
{"title":"Production decline curve analysis of shale oil wells: A case study of Bakken, Eagle Ford and Permian","authors":"Hui-Ying Tang, Ge He, Ying-Ying Ni, Da Huo, Yu-Long Zhao, Liang Xue, Lie-Hui Zhang","doi":"10.1016/j.petsci.2024.07.029","DOIUrl":"https://doi.org/10.1016/j.petsci.2024.07.029","url":null,"abstract":"The shale revolution has turned the United States from an oil importer into an oil exporter. The success of shale oil production in the U.S. has inspired many countries, including China, to begin the exploitation and development of shale oil resources. In this study, the production curves of over 30,000 shale oil wells in the Bakken, Eagle Ford (EF), and Permian are systematically analyzed to provide reference and guidance for future shale oil development. To find out the most suitable decline curve models for shale oil wells, fifteen models and a new fitting method are tested on wells with production history over 6 years. Interestingly, all basins show similar results despite of their varieties in geological conditions: stretched exponential production decline (SEPD) + Arps model provides most accurate prediction of estimated ultimate recovery (EUR) for wells with over 2 years' production, while the Arps model can be used before the two years’ switch point. With the EUR calculated by decline curve analysis, we further construct simple regression models for different basins to predict the EUR quickly and early. This work helps us better understand the production of shale oil wells, as well as provide important suggestions for the choices of models for shale oil production prediction.","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"113 1","pages":""},"PeriodicalIF":5.6,"publicationDate":"2024-08-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142180078","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2024-08-01DOI: 10.1016/j.petsci.2024.01.019
This study aims to analysis the influence of economic growth (EG) and energy consumption (EC) on sulfur dioxide emissions (SE) in China. Accordingly, this study explores the link between EG, EC, and SE for 30 provinces in China over the span of 2000–2019. This study also analyzes cross-sectional dependence tests, panel unit root tests, Westerlund panel cointegration tests, Dumitrescu-Hurlin (D-H) causality tests. According to the test results, there is an inverted U-shaped association between EG and SE, and the assumption of the Environmental Kuznets Curve (EKC) is verified. The signs of EG and EC in the fixed effect (FE) and random effect (RE) methods are in line with those in the dynamic ordinary least squares (DOLS), fully modified ordinary least squares (FMOLS) and autoregressive distributed lag (ARDL) estimators. Moreover, the results verified that EC can obviously positive impact the SE. To reduce SE in China, government and policymakers can improve air quality by developing cleaner energy sources and improving energy efficiency. This requires the comprehensive use of policies, regulations, economic incentives, and public participation to promote sustainable development.
本研究旨在分析中国经济增长（EG）和能源消耗（EC）对二氧化硫排放（SE）的影响。因此，本研究探讨了 2000-2019 年间中国 30 个省份的经济增长、能源消耗和二氧化硫排放之间的联系。本研究还分析了截面依存检验、面板单位根检验、Westerlund 面板协整检验、Dumitrescu-Hurlin（D-H）因果检验。检验结果表明，EG 与 SE 之间存在倒 U 型关联，验证了环境库兹涅茨曲线（EKC）假设。在固定效应（FE）和随机效应（RE）方法中，EG 和 EC 的符号与 DOLS、FMOLS 和 ARDL 估计中的符号一致。此外，结果还验证了 EC 对 SE 有明显的正向影响。为了降低中国的 SE，政府和政策制定者可以通过发展清洁能源和提高能源效率来改善空气质量。这需要综合运用政策、法规、经济激励和公众参与等手段，促进可持续发展。
{"title":"Exploring the impact of economic growth and energy consumption on SO2 emissions in China based on the Environmental Kuznets Curve hypothesis","authors":"","doi":"10.1016/j.petsci.2024.01.019","DOIUrl":"10.1016/j.petsci.2024.01.019","url":null,"abstract":"<div><p>This study aims to analysis the influence of economic growth (EG) and energy consumption (EC) on sulfur dioxide emissions (SE) in China. Accordingly, this study explores the link between EG, EC, and SE for 30 provinces in China over the span of 2000–2019. This study also analyzes cross-sectional dependence tests, panel unit root tests, Westerlund panel cointegration tests, Dumitrescu-Hurlin (D-H) causality tests. According to the test results, there is an inverted U-shaped association between EG and SE, and the assumption of the Environmental Kuznets Curve (EKC) is verified. The signs of EG and EC in the fixed effect (FE) and random effect (RE) methods are in line with those in the dynamic ordinary least squares (DOLS), fully modified ordinary least squares (FMOLS) and autoregressive distributed lag (ARDL) estimators. Moreover, the results verified that EC can obviously positive impact the SE. To reduce SE in China, government and policymakers can improve air quality by developing cleaner energy sources and improving energy efficiency. This requires the comprehensive use of policies, regulations, economic incentives, and public participation to promote sustainable development.</p></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"21 4","pages":"Pages 2892-2900"},"PeriodicalIF":6.0,"publicationDate":"2024-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S1995822624000190/pdfft?md5=0ddf4fcd23bf640debf4be5e69df626f&pid=1-s2.0-S1995822624000190-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139646544","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2024-08-01DOI: 10.1016/j.petsci.2024.03.017
It remains a great challenge to understand the hydrates involved in phenomena in practical oil and gas systems. The adhesion forces between hydrate particles, between hydrate particles and pipe walls, and between hydrate particles and reservoir particles are essential factors that control the behaviors of clathrate hydrates in different applications. In this review, we summarize the typical micro-force measurement apparatus and methods utilized to study hydrate particle systems. In addition, the adhesion test results, the related understandings, and the applied numerical calculation models are systematically discussed.
{"title":"Research progress on micro-force measurement of a hydrate particle system","authors":"","doi":"10.1016/j.petsci.2024.03.017","DOIUrl":"10.1016/j.petsci.2024.03.017","url":null,"abstract":"<div><p>It remains a great challenge to understand the hydrates involved in phenomena in practical oil and gas systems. The adhesion forces between hydrate particles, between hydrate particles and pipe walls, and between hydrate particles and reservoir particles are essential factors that control the behaviors of clathrate hydrates in different applications. In this review, we summarize the typical micro-force measurement apparatus and methods utilized to study hydrate particle systems. In addition, the adhesion test results, the related understandings, and the applied numerical calculation models are systematically discussed.</p></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"21 4","pages":"Pages 2169-2183"},"PeriodicalIF":6.0,"publicationDate":"2024-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S1995822624000840/pdfft?md5=0578aa9998c5fd8b1bc4436c46eee913&pid=1-s2.0-S1995822624000840-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140403207","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2024-08-01DOI: 10.1016/j.petsci.2024.04.008
Radial well filled with phase change material has been proposed as a novel sand control method for hydrate exploitation. In order to reveal the sand control mechanism, CFD-DEM coupling method is applied to simulate the migration, settlement, and blockage processes of sand particles in the radial well. The obtained results indicate that three scenarios have been recognized for sand particles passing through sand control medium, based on the diameter ratio of sand control medium to sand particle (Dd): fully passing (Dd = 8.75–22.5), partially passing and partially blocked (Dd = 3.18–5.63), and completely blocked (Dd = 2.18–3.21). After being captured by the sand control medium, sand particles can block pores, which increases fluid flow resistance and causes a certain pressure difference in the radial well. The pressure in the radial well should be lower than the hydrate phase equilibrium pressure during sand control design, for the purpose of promoting hydrate decomposition, and sand capture. The length of the radial well should be optimized based on the reservoir pore pressure, production pressure difference, bottom hole pressure, and the pressure gradient in the radial well. It should be noticed that the sand control medium leads to a decrease in permeability after sand particles captured. Even the permeability is reduced to several hundred millidarcy, it is still sufficient to ensure the effective flow of gas and water after hydrate decomposition. Increasing fluid velocity reduces the blocking capacity of the sand control medium, mainly because of deterioration in bridging between sand particles.
{"title":"Sand control mechanism of radial well filled with phase change material in hydrate reservoir","authors":"","doi":"10.1016/j.petsci.2024.04.008","DOIUrl":"10.1016/j.petsci.2024.04.008","url":null,"abstract":"<div><p>Radial well filled with phase change material has been proposed as a novel sand control method for hydrate exploitation. In order to reveal the sand control mechanism, CFD-DEM coupling method is applied to simulate the migration, settlement, and blockage processes of sand particles in the radial well. The obtained results indicate that three scenarios have been recognized for sand particles passing through sand control medium, based on the diameter ratio of sand control medium to sand particle (<em>D</em><sub>d</sub>): fully passing (<em>D</em><sub>d</sub> = 8.75–22.5), partially passing and partially blocked (<em>D</em><sub>d</sub> = 3.18–5.63), and completely blocked (<em>D</em><sub>d</sub> = 2.18–3.21). After being captured by the sand control medium, sand particles can block pores, which increases fluid flow resistance and causes a certain pressure difference in the radial well. The pressure in the radial well should be lower than the hydrate phase equilibrium pressure during sand control design, for the purpose of promoting hydrate decomposition, and sand capture. The length of the radial well should be optimized based on the reservoir pore pressure, production pressure difference, bottom hole pressure, and the pressure gradient in the radial well. It should be noticed that the sand control medium leads to a decrease in permeability after sand particles captured. Even the permeability is reduced to several hundred millidarcy, it is still sufficient to ensure the effective flow of gas and water after hydrate decomposition. Increasing fluid velocity reduces the blocking capacity of the sand control medium, mainly because of deterioration in bridging between sand particles.</p></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"21 4","pages":"Pages 2571-2582"},"PeriodicalIF":6.0,"publicationDate":"2024-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S1995822624001079/pdfft?md5=b84610ec56c6825202642a0a48a2e5f9&pid=1-s2.0-S1995822624001079-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140777558","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2024-08-01DOI: 10.1016/j.petsci.2024.04.012
The environmental hazards and "carbon footprint" of oil and gas drilling can be significantly reduced by replacing traditional petroleum-based chemical additives with natural materials derived from plants and animals. This paper explored for the first time the interaction mechanism between natural rubber latex (NRL) and bentonite suspensions (BTs) through a series of characterization experiments, as well as the potential applications in water-based drilling fluids (WBDF). The gel viscoelasticity experiments showed that NRL could decrease the consistency coefficient (k) and flow index (n) of BTs, and enhance the shear thinning performance of BTs as pseudo-plastic fluids. In addition, 0.5 w/v% NRL not only increased the critical yield stress and strengthened the structural strength between the bentonite particles, but also facilitated the compatibility of pressure loss and flow efficiency. The evaluation of colloidal stability and WBDF performance indicated that NRL particles could promote the hydration and charge stability on the surface of BTs particles, and optimize the particle size distribution and flow resistance of WBDF under the "intercalation-exfoliation-encapsulation" synergistic interaction. Moreover, NRL can improve the rheological properties of WBDF at high temperatures (<150 °C), and form a dense blocking layer by bridging and sealing the pores and cracks of the filter cake, which ultimately reduces the permeability of the cake and the filtration loss of WBDF.
{"title":"Natural rubber latex as a potential additive for water-based drilling fluids","authors":"","doi":"10.1016/j.petsci.2024.04.012","DOIUrl":"10.1016/j.petsci.2024.04.012","url":null,"abstract":"<div><p>The environmental hazards and \"carbon footprint\" of oil and gas drilling can be significantly reduced by replacing traditional petroleum-based chemical additives with natural materials derived from plants and animals. This paper explored for the first time the interaction mechanism between natural rubber latex (NRL) and bentonite suspensions (BTs) through a series of characterization experiments, as well as the potential applications in water-based drilling fluids (WBDF). The gel viscoelasticity experiments showed that NRL could decrease the consistency coefficient (<em>k</em>) and flow index (<em>n</em>) of BTs, and enhance the shear thinning performance of BTs as pseudo-plastic fluids. In addition, 0.5 w/v% NRL not only increased the critical yield stress and strengthened the structural strength between the bentonite particles, but also facilitated the compatibility of pressure loss and flow efficiency. The evaluation of colloidal stability and WBDF performance indicated that NRL particles could promote the hydration and charge stability on the surface of BTs particles, and optimize the particle size distribution and flow resistance of WBDF under the \"intercalation-exfoliation-encapsulation\" synergistic interaction. Moreover, NRL can improve the rheological properties of WBDF at high temperatures (<150 °C), and form a dense blocking layer by bridging and sealing the pores and cracks of the filter cake, which ultimately reduces the permeability of the cake and the filtration loss of WBDF.</p></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"21 4","pages":"Pages 2677-2687"},"PeriodicalIF":6.0,"publicationDate":"2024-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S1995822624001110/pdfft?md5=9b839dc5a6e1c3d3cab169c4a1b5adba&pid=1-s2.0-S1995822624001110-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140929619","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
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