Pub Date : 2021-05-24DOI: 10.3997/2214-4609.202154081
I. Karimov, B. Plotnikov, R. Volkov, D. Ignatova
Summary Unconventional reservoirs, in terms of their totality of properties, are unique geological objects for which there are no generally accepted and widely tested effective methods for studying cores, interpreting well logging and seismic forecasting. For the effective development of this type of reservoir, as a rule, horizontal wells with multistage hydraulic fracturing are used, providing the maximum possible stimulated volume of rocks (SRV) and an increase in the initial and accumulated production rates. The result of hydraulic fracturing largely depends on the brittleness of the rocks and the presence of zones of natural fracturing. Prediction of these properties in the interwell spacing is a complex task that requires modern seismic processing and interpretation approaches
{"title":"Unconventional reservoirs brittleness prediction for improving multistage hydraulic fracturing efficiency in horizontal wells","authors":"I. Karimov, B. Plotnikov, R. Volkov, D. Ignatova","doi":"10.3997/2214-4609.202154081","DOIUrl":"https://doi.org/10.3997/2214-4609.202154081","url":null,"abstract":"Summary Unconventional reservoirs, in terms of their totality of properties, are unique geological objects for which there are no generally accepted and widely tested effective methods for studying cores, interpreting well logging and seismic forecasting. For the effective development of this type of reservoir, as a rule, horizontal wells with multistage hydraulic fracturing are used, providing the maximum possible stimulated volume of rocks (SRV) and an increase in the initial and accumulated production rates. The result of hydraulic fracturing largely depends on the brittleness of the rocks and the presence of zones of natural fracturing. Prediction of these properties in the interwell spacing is a complex task that requires modern seismic processing and interpretation approaches","PeriodicalId":105144,"journal":{"name":"Horizontal Wells 2021","volume":"8 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-05-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116692482","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}
Pub Date : 2021-05-24DOI: 10.3997/2214-4609.202154030
S. S. Soshnikov, E. Cherepanov
Summary The object of this work was a large oil and gas condensate carbonate field in Eastern Siberia. The target interval at the field is the riphean reservoirs, which are represented by an impermeable carbonate matrix permeated by a dense network of micro-macro cracks of various orientations, caverns and leaching intervals. The affected area was subjected to an active and multi-stage tectonic impact, which led to the widespread development of numerous low-amplitude, sub-vertical faults and fracture zones of a predominantly shear nature. The main intervals of the section are represented by the Archean basement, Proterozoic (Riphean-Vend), Paleozoic (Cambrian, Ordovician, etc.) and Upper (HCR) parts of the section. The Paleozoic part of the section consists mainly of Cambrian carbonate-halogen-sulfate rocks and traps, presumably of Triassic age. The wave pattern of the Cambrian rocks is characterized by relatively laterally sustained seismic reflections with a small number of interpreted faults. The shape of the wave pattern, or in other words, the seismic images/seismophations, are mainly high-amplitude, laterally sustained with increased reflection and impedance coefficients. Potential reservoirs in this part of the section are most often represented by relatively dense carbonates, which are characterized by a small number of secondary changes in carbonate rocks. The main risks when drilling GS are the presence of abnormally high absorption of drilling fluid (up to loss of circulation), the presence of tool failures, frequent wear of bits, the presence of silicification. More than half of the current fund of producing wells have a high gas factor or significant water cut. To solve the described problems, it was decided to create a number of criteria for laying horizontal wells, taking into account the seismogeological conditions of the section.
{"title":"Elaboration of criteria for laying wells of the operating stock of the Riphean carbonate reservoir in the central part of the Kamovsky arch of the Baikit anteclise based on 3D seismic data","authors":"S. S. Soshnikov, E. Cherepanov","doi":"10.3997/2214-4609.202154030","DOIUrl":"https://doi.org/10.3997/2214-4609.202154030","url":null,"abstract":"Summary The object of this work was a large oil and gas condensate carbonate field in Eastern Siberia. The target interval at the field is the riphean reservoirs, which are represented by an impermeable carbonate matrix permeated by a dense network of micro-macro cracks of various orientations, caverns and leaching intervals. The affected area was subjected to an active and multi-stage tectonic impact, which led to the widespread development of numerous low-amplitude, sub-vertical faults and fracture zones of a predominantly shear nature. The main intervals of the section are represented by the Archean basement, Proterozoic (Riphean-Vend), Paleozoic (Cambrian, Ordovician, etc.) and Upper (HCR) parts of the section. The Paleozoic part of the section consists mainly of Cambrian carbonate-halogen-sulfate rocks and traps, presumably of Triassic age. The wave pattern of the Cambrian rocks is characterized by relatively laterally sustained seismic reflections with a small number of interpreted faults. The shape of the wave pattern, or in other words, the seismic images/seismophations, are mainly high-amplitude, laterally sustained with increased reflection and impedance coefficients. Potential reservoirs in this part of the section are most often represented by relatively dense carbonates, which are characterized by a small number of secondary changes in carbonate rocks. The main risks when drilling GS are the presence of abnormally high absorption of drilling fluid (up to loss of circulation), the presence of tool failures, frequent wear of bits, the presence of silicification. More than half of the current fund of producing wells have a high gas factor or significant water cut. To solve the described problems, it was decided to create a number of criteria for laying horizontal wells, taking into account the seismogeological conditions of the section.","PeriodicalId":105144,"journal":{"name":"Horizontal Wells 2021","volume":"9 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-05-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126693488","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}
Pub Date : 2021-05-24DOI: 10.3997/2214-4609.202154073
A. M. Yanaev, A. Lisitsyn, P.V. Lupanov, D. Korobitsyn, V. Karpov, N. Parshin
Summary The object of the research is the Upper Jurassic deposits YuK-01 of the Sredne-Nazym field. The main features of the Yak-01 Upper Jurassic deposits are the complexity of the structure of the deposits, high heterogeneity of properties along the section, lateral and ultra-low matrix permeability. Currently, it remains relevant to determine the approach to the development of hydraulic fracturing designs in the field. The main difficulty is the lack of research, which makes it difficult to find solutions at the design and execution stages. An incomplete set of well logging leads to the impossibility of building a correlation between well flow rates and hydraulic fracturing designs. At the initial stage of development, vertical wells were completed with hydraulic fracturing using a "standard" design. “Standart” design is an injection schedule of 30 tons of proppant with a constant increase in the concentration of proppant (hereinafter CSP), injected onto a cross-linked gel with a flow rate of 3.5–4.5 m3/min, which limited the possibility of changing other technological parameters’ hydraulic fracturing, such as: volume and viscosity of the liquid; the volume of the buffer stage; mass and concentration of proppant, etc. This article presents the developed approach to the design of hydraulic fracturing schedules in the Sredne-Nazymskoye field and the results of its application. Additional attention is paid to highlighting the process of developing hydraulic fracturing schedules, as a result of which the proposed approach was developed.
{"title":"Development of an approach for hydraulic fracturing operations and a decision-making methodology in the Sredne-Nazymskoye field","authors":"A. M. Yanaev, A. Lisitsyn, P.V. Lupanov, D. Korobitsyn, V. Karpov, N. Parshin","doi":"10.3997/2214-4609.202154073","DOIUrl":"https://doi.org/10.3997/2214-4609.202154073","url":null,"abstract":"Summary The object of the research is the Upper Jurassic deposits YuK-01 of the Sredne-Nazym field. The main features of the Yak-01 Upper Jurassic deposits are the complexity of the structure of the deposits, high heterogeneity of properties along the section, lateral and ultra-low matrix permeability. Currently, it remains relevant to determine the approach to the development of hydraulic fracturing designs in the field. The main difficulty is the lack of research, which makes it difficult to find solutions at the design and execution stages. An incomplete set of well logging leads to the impossibility of building a correlation between well flow rates and hydraulic fracturing designs. At the initial stage of development, vertical wells were completed with hydraulic fracturing using a \"standard\" design. “Standart” design is an injection schedule of 30 tons of proppant with a constant increase in the concentration of proppant (hereinafter CSP), injected onto a cross-linked gel with a flow rate of 3.5–4.5 m3/min, which limited the possibility of changing other technological parameters’ hydraulic fracturing, such as: volume and viscosity of the liquid; the volume of the buffer stage; mass and concentration of proppant, etc. This article presents the developed approach to the design of hydraulic fracturing schedules in the Sredne-Nazymskoye field and the results of its application. Additional attention is paid to highlighting the process of developing hydraulic fracturing schedules, as a result of which the proposed approach was developed.","PeriodicalId":105144,"journal":{"name":"Horizontal Wells 2021","volume":"17 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-05-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123845539","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}
Pub Date : 2021-05-24DOI: 10.3997/2214-4609.202154046
I. Novikov, А.А. Alekseev, M. Zimoglyad, L. Samigullin, V.M. Nagovitsyn, A.Y. Bydzan, D. Vasechkin
Summary There are the remaining undeveloped hydrocarbon reserves at Novoportovskoye field occurring immediately under massive gas caps. To make field development economical in such geological settings, new technologies are required. This article describes the experience of constructing a multilateral well according to the new TAML Level 1 completion scheme, utilizing rock characteristics of the impermeable roof of the underlying bed and the dynamic Quantum PLT to arrange for separate production metering from each formation. Multilateral wells have been extensively drilled in the Novoportovskoye field in order to expand the drainage area. The dynamic production logging technology based on the use of quantum dot marker-reporters was chosen to arrange for separate production metering. The CAPEX and construction period have decreased by about 38%. The design enables separate production metering from each reservoir without stopping production. In addition, the costs associated with the regular interpretation of data obtained by analyzing the samples containing quantum-dot markers are offset by a reduction in operating costs for the pumping unit and service of well workover teams. The operator company has resolved to replicate the technology. However, the potential for this scale-up is limited by the requirements for the geological structure of the section.
{"title":"Separate Production Metering From Each Formation When Integrating Taml-1 Well Construction Technology with Quantum Plt at The Novoportovskoye Field","authors":"I. Novikov, А.А. Alekseev, M. Zimoglyad, L. Samigullin, V.M. Nagovitsyn, A.Y. Bydzan, D. Vasechkin","doi":"10.3997/2214-4609.202154046","DOIUrl":"https://doi.org/10.3997/2214-4609.202154046","url":null,"abstract":"Summary There are the remaining undeveloped hydrocarbon reserves at Novoportovskoye field occurring immediately under massive gas caps. To make field development economical in such geological settings, new technologies are required. This article describes the experience of constructing a multilateral well according to the new TAML Level 1 completion scheme, utilizing rock characteristics of the impermeable roof of the underlying bed and the dynamic Quantum PLT to arrange for separate production metering from each formation. Multilateral wells have been extensively drilled in the Novoportovskoye field in order to expand the drainage area. The dynamic production logging technology based on the use of quantum dot marker-reporters was chosen to arrange for separate production metering. The CAPEX and construction period have decreased by about 38%. The design enables separate production metering from each reservoir without stopping production. In addition, the costs associated with the regular interpretation of data obtained by analyzing the samples containing quantum-dot markers are offset by a reduction in operating costs for the pumping unit and service of well workover teams. The operator company has resolved to replicate the technology. However, the potential for this scale-up is limited by the requirements for the geological structure of the section.","PeriodicalId":105144,"journal":{"name":"Horizontal Wells 2021","volume":"16 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-05-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122254672","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}
Pub Date : 2021-05-24DOI: 10.3997/2214-4609.202154037
A.V. Iakovenko, D. Lachugin, A. Maltsev, T.Y Dolgushin, N. Kudlaeva, J.J. Polushina
Summary Well 2 is 4 branches fishbone with total reservoir exposure 3100 m The drillability of final design decisions is proven and wells are brought into operations. The better result is shown by Well 1: the productivity index is more, then expected from numerical simulation. Extended well test is in progress. Build up test show, that 64% of well is in production"
{"title":"Multilateral wells as the way to increase profitability of Vikulskaya formation development","authors":"A.V. Iakovenko, D. Lachugin, A. Maltsev, T.Y Dolgushin, N. Kudlaeva, J.J. Polushina","doi":"10.3997/2214-4609.202154037","DOIUrl":"https://doi.org/10.3997/2214-4609.202154037","url":null,"abstract":"Summary Well 2 is 4 branches fishbone with total reservoir exposure 3100 m The drillability of final design decisions is proven and wells are brought into operations. The better result is shown by Well 1: the productivity index is more, then expected from numerical simulation. Extended well test is in progress. Build up test show, that 64% of well is in production\"","PeriodicalId":105144,"journal":{"name":"Horizontal Wells 2021","volume":"40 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-05-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131077220","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}
Pub Date : 2021-05-24DOI: 10.3997/2214-4609.202154045
E. Malyavko, S. Shtun, A. Senkov, O. Abramenko, А.V. Buyanov, D. Lysova, E. V. Potapova
Summary Fundamentally new control tools for reservoir management are required in modern field tests for productivity estimation with high efficiency. One such tool is marker-based production logging enabling long-term production profiling surveillance. This research represents the case study of multi-phase flow profile estimation (oil, water and gas) in horizontal offshore oil wells in the North Caspian Sea. This method assumes that marker systems (marker cassettes) with unique codes are placed in the well as part of the lower completion. During further monitoring immediately after the well is put into production, formation fluid sampling is performed with a certain frequency according to a pre-formed schedule. The fluid and gas samples are analysed in the laboratory using specialised equipment. Based on the processing results, the distribution of each marker code was obtained. It shows the intensity of fluid flow from the formation into the wellbore. The results of production logging for each interval made it possible to determine the zones with low productivity, to identify how they correlate with the geological features of the area and the porosity and permeability distribution throughout the reservoir, and also to reveal the dependence of the production profile on well operation parameters. This information allows optimising the well operation and selecting the most promising development scenario to maximise hydrocarbon recovery.
{"title":"Marker-Based Long-Term Production Profiling Surveillance in Horizontal Wells in The Northern Capsian Sea","authors":"E. Malyavko, S. Shtun, A. Senkov, O. Abramenko, А.V. Buyanov, D. Lysova, E. V. Potapova","doi":"10.3997/2214-4609.202154045","DOIUrl":"https://doi.org/10.3997/2214-4609.202154045","url":null,"abstract":"Summary Fundamentally new control tools for reservoir management are required in modern field tests for productivity estimation with high efficiency. One such tool is marker-based production logging enabling long-term production profiling surveillance. This research represents the case study of multi-phase flow profile estimation (oil, water and gas) in horizontal offshore oil wells in the North Caspian Sea. This method assumes that marker systems (marker cassettes) with unique codes are placed in the well as part of the lower completion. During further monitoring immediately after the well is put into production, formation fluid sampling is performed with a certain frequency according to a pre-formed schedule. The fluid and gas samples are analysed in the laboratory using specialised equipment. Based on the processing results, the distribution of each marker code was obtained. It shows the intensity of fluid flow from the formation into the wellbore. The results of production logging for each interval made it possible to determine the zones with low productivity, to identify how they correlate with the geological features of the area and the porosity and permeability distribution throughout the reservoir, and also to reveal the dependence of the production profile on well operation parameters. This information allows optimising the well operation and selecting the most promising development scenario to maximise hydrocarbon recovery.","PeriodicalId":105144,"journal":{"name":"Horizontal Wells 2021","volume":"5 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-05-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114944611","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}
Pub Date : 2021-05-24DOI: 10.3997/2214-4609.202154082
A. Agishev, A. Nurgaliev
Summary There is a tendency to complicate drilling techniques in the Russian Federation and in the world. It is caused by increase the number of horizontal wells and increase the length of the laterals. Casing with thread connections while run in hole operation in deviated and horizontal wells are subjected to combined loads caused by axial load, bending load, differential pressure. The most critical point of casing string is the thread connection. 50%-80% compression efficiency of connection becomes insufficient. This article describes results of FEA (finite element analysis) for API Buttress and TMK UP CWB connections and full scale test for TMK UP CWB 177.8 х 9.19 N80.
在俄罗斯联邦和世界范围内，有一种使钻井技术复杂化的趋势。这是由于水平井数量的增加和分支井长度的增加造成的。在斜井和水平井下入过程中，带螺纹连接的套管承受轴向载荷、弯曲载荷、压差等综合载荷。套管柱最关键的环节是螺纹连接。连接压缩效率达不到50% ~ 80%。本文描述了API Buttress和TMK UP CWB连接的有限元分析结果，以及TMK UP CWB 177.8 × 9.19 N80的全尺寸试验结果。
{"title":"Performance of casing connection for horizontal oil wells","authors":"A. Agishev, A. Nurgaliev","doi":"10.3997/2214-4609.202154082","DOIUrl":"https://doi.org/10.3997/2214-4609.202154082","url":null,"abstract":"Summary There is a tendency to complicate drilling techniques in the Russian Federation and in the world. It is caused by increase the number of horizontal wells and increase the length of the laterals. Casing with thread connections while run in hole operation in deviated and horizontal wells are subjected to combined loads caused by axial load, bending load, differential pressure. The most critical point of casing string is the thread connection. 50%-80% compression efficiency of connection becomes insufficient. This article describes results of FEA (finite element analysis) for API Buttress and TMK UP CWB connections and full scale test for TMK UP CWB 177.8 х 9.19 N80.","PeriodicalId":105144,"journal":{"name":"Horizontal Wells 2021","volume":"58 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-05-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125078532","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}
Pub Date : 2021-05-24DOI: 10.3997/2214-4609.202154059
K. A. Meshcheryakov, Yu.V. Fefelov, A. V. Shirokov
Summary The results of drilling extended reach wells at one of the fields in the north of the Perm region are presented. The substantiation of the choice of the well design and the extended profile taking into account the peculiarities of the geological structure of the field is given. The problems that arose during the construction of the well and their solutions are described. The relevance of individual design of construction of extended reach wells is noted.
{"title":"Construction of Extended-Reach Wells (Bottomhole More Than 6000 m) in the North of the Perm Region","authors":"K. A. Meshcheryakov, Yu.V. Fefelov, A. V. Shirokov","doi":"10.3997/2214-4609.202154059","DOIUrl":"https://doi.org/10.3997/2214-4609.202154059","url":null,"abstract":"Summary The results of drilling extended reach wells at one of the fields in the north of the Perm region are presented. The substantiation of the choice of the well design and the extended profile taking into account the peculiarities of the geological structure of the field is given. The problems that arose during the construction of the well and their solutions are described. The relevance of individual design of construction of extended reach wells is noted.","PeriodicalId":105144,"journal":{"name":"Horizontal Wells 2021","volume":"42 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-05-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121179927","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}
Pub Date : 2021-05-24DOI: 10.3997/2214-4609.202154012
D. Khasanov, J. V. Gubaidullina, K.V. Rodionov, I. Bagmanov, D. Nurgaliev, A. Lutfullin
Summary Complex of methods, presented in this work, allows to identify active fluid migration zones of natural or technogenic characters. Application of this complex is especially relevant due to existing areas, which underexplored or not explored by seismic methods. The proposed method allows to promptly predict the existence and spatial position of sedimentary cover active fluid migration zones at minimum cost. In such zones, the fluid migration can occur laterally (along faults, blocks boundaries, etc) and vertically. The information, which obtained using this technique, can be applied for planning of horizontal wells and network of injection wells, interpreting hydrodynamic modeling data etc.
{"title":"The approach for anomalous permeable zones detection in the sedimentary cover based on geomorphological analysis and gravimetric data","authors":"D. Khasanov, J. V. Gubaidullina, K.V. Rodionov, I. Bagmanov, D. Nurgaliev, A. Lutfullin","doi":"10.3997/2214-4609.202154012","DOIUrl":"https://doi.org/10.3997/2214-4609.202154012","url":null,"abstract":"Summary Complex of methods, presented in this work, allows to identify active fluid migration zones of natural or technogenic characters. Application of this complex is especially relevant due to existing areas, which underexplored or not explored by seismic methods. The proposed method allows to promptly predict the existence and spatial position of sedimentary cover active fluid migration zones at minimum cost. In such zones, the fluid migration can occur laterally (along faults, blocks boundaries, etc) and vertically. The information, which obtained using this technique, can be applied for planning of horizontal wells and network of injection wells, interpreting hydrodynamic modeling data etc.","PeriodicalId":105144,"journal":{"name":"Horizontal Wells 2021","volume":"48 11","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-05-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114003993","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}
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