A. E. Folomeev, A. F. Magadiev, A. R. Khatmullin, Ildar Azatovich Taipov, S. Vakhrushev, T. R. Galiev, Flyus Khanifovich Mukhametov
The article demonstrates the results of experimental and field studies of the thermal foam-acid treatment technology with the use of water solutions of heat and gas generating system. The potential temperature of the heat-generating reaction upon mixing of agents was estimated in laboratory conditions and the physical and chemical properties of acid solutions were determined. A series of filtration experiments was conducted on treating dolomitized core samples with a basic hydrochloric acid solution.The constant of the rate of reaction between the basic acid solution and dolomitized carbonate rock was determined based on the experiment results. The article provides a brief analytical overview of world experience of the thermochemical treatment of the bottomhole area. The technology selected for the tests called thermo-foam-acid and implies the step-by-step injection of water heat and gas generating solutions with an addition of surfactants and an initiator into the bottomhole area. The heat-generating reaction is accompanied by the generation of a large amount of heat, gases and hot foamed acid. Heating melts high molecular weight oil compounds, washes oil sheen from rock surface and increases the speed of its dissolution with hydrochloric acid. This foam acts as a diverter for the next portion of active acid and prevents undesired stimulation of high-permeability interlayers and fractures. Surfactants in the acid solution increase its ability to penetrate pores and microfractures. The physical modeling of a thermal foam-acid treatment has been performed. Arlanskoe (Kashirskian-Podolskian deposits) and Nadezhdinskoe (Famennian stage) fields where carbonate formations are characterized by high and increased oil viscosity, low reservoir temperature, fractured and dolomitized reservoirs were selected as a site to perform field tests. Well operation at these formations is complicated by the precipitation of asphaltenes, resins and paraffins in the bottomhole area. Solution injection parameters were recorded during treatments based on this technology. The technological efficiency of this treatment was confirmed based on bottomhole pressure and temperature changes during injection operations. Technology efficiency was analyzed and the well flow rate was monitored based on the field test results. The main stages of this work are shown in Figure 1.Figure. 1Project stages
{"title":"Acidizing Combined with Heat Generating System in Low-Temperature Dolomitized Wax Damaged Carbonates","authors":"A. E. Folomeev, A. F. Magadiev, A. R. Khatmullin, Ildar Azatovich Taipov, S. Vakhrushev, T. R. Galiev, Flyus Khanifovich Mukhametov","doi":"10.2118/202069-ms","DOIUrl":"https://doi.org/10.2118/202069-ms","url":null,"abstract":"\u0000 The article demonstrates the results of experimental and field studies of the thermal foam-acid treatment technology with the use of water solutions of heat and gas generating system. The potential temperature of the heat-generating reaction upon mixing of agents was estimated in laboratory conditions and the physical and chemical properties of acid solutions were determined. A series of filtration experiments was conducted on treating dolomitized core samples with a basic hydrochloric acid solution.The constant of the rate of reaction between the basic acid solution and dolomitized carbonate rock was determined based on the experiment results.\u0000 The article provides a brief analytical overview of world experience of the thermochemical treatment of the bottomhole area. The technology selected for the tests called thermo-foam-acid and implies the step-by-step injection of water heat and gas generating solutions with an addition of surfactants and an initiator into the bottomhole area. The heat-generating reaction is accompanied by the generation of a large amount of heat, gases and hot foamed acid. Heating melts high molecular weight oil compounds, washes oil sheen from rock surface and increases the speed of its dissolution with hydrochloric acid. This foam acts as a diverter for the next portion of active acid and prevents undesired stimulation of high-permeability interlayers and fractures. Surfactants in the acid solution increase its ability to penetrate pores and microfractures. The physical modeling of a thermal foam-acid treatment has been performed.\u0000 Arlanskoe (Kashirskian-Podolskian deposits) and Nadezhdinskoe (Famennian stage) fields where carbonate formations are characterized by high and increased oil viscosity, low reservoir temperature, fractured and dolomitized reservoirs were selected as a site to perform field tests. Well operation at these formations is complicated by the precipitation of asphaltenes, resins and paraffins in the bottomhole area.\u0000 Solution injection parameters were recorded during treatments based on this technology. The technological efficiency of this treatment was confirmed based on bottomhole pressure and temperature changes during injection operations. Technology efficiency was analyzed and the well flow rate was monitored based on the field test results.\u0000 The main stages of this work are shown in Figure 1.Figure. 1Project stages","PeriodicalId":359083,"journal":{"name":"Day 2 Tue, October 27, 2020","volume":"16 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116217672","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}
N. Vikulin, V. A. Rusakov, A. A. Aliyev, Oleg Igorevich Mityaev
This article includes review of evolution of multistage fracturing completions for conventional oil reserves in continental Russia and focuses on attempts of the LLC "RN-Yuganskneftegaz", the one of the largest operator company in Russia, to solve the challenge of well life extension by implementing new completion technologies allowing reliable means of re-fracturing on the well after several years of service as well as the means to isolate gas or water break-through. A comparative analysis of different types of multistage fracturing completions was performed by LLC "RN-Yuganskneftegaz" with the aim to select the most suitable technology to address the above-mentioned goals without sacrifice of time required to drill, complete and stimulate the well. As the result of the analysis the technology of the frac valves activated by single-sized dissolvable balls was selected as a most appropriate. The successful field trial on 2 wells is described in this paper.
{"title":"New Opportunities for Multistage Stimulation Design - Frac Sleeves Activated by Single-Sized Dissolvable Balls","authors":"N. Vikulin, V. A. Rusakov, A. A. Aliyev, Oleg Igorevich Mityaev","doi":"10.2118/201853-ms","DOIUrl":"https://doi.org/10.2118/201853-ms","url":null,"abstract":"\u0000 This article includes review of evolution of multistage fracturing completions for conventional oil reserves in continental Russia and focuses on attempts of the LLC \"RN-Yuganskneftegaz\", the one of the largest operator company in Russia, to solve the challenge of well life extension by implementing new completion technologies allowing reliable means of re-fracturing on the well after several years of service as well as the means to isolate gas or water break-through.\u0000 A comparative analysis of different types of multistage fracturing completions was performed by LLC \"RN-Yuganskneftegaz\" with the aim to select the most suitable technology to address the above-mentioned goals without sacrifice of time required to drill, complete and stimulate the well.\u0000 As the result of the analysis the technology of the frac valves activated by single-sized dissolvable balls was selected as a most appropriate. The successful field trial on 2 wells is described in this paper.","PeriodicalId":359083,"journal":{"name":"Day 2 Tue, October 27, 2020","volume":"33 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124967649","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}
Andrey Garipov, D. Tur, A. Galimkhanov, Almaz Khalilov, A. Yavorsky, V. Maltsev, V. Pogurets, Aleksey Rybalkin
This paper describes the results of efficient cooperation between the Operator, the General Drilling Contractor and the Service Company, who participated in the construction of horizontal wells in Yuzhno-Tambeyskoye gas condensate field. This document describes an integrated engineering approach to selection of new technical and technological solutions, which safely achieved all the geological tasks while constructing the wells. The key innovations of real-time data transmission from downhole tools, allowed the quality of the information received to be improved which increased the average rate of penetration (ROP) and reduced the well drilling time. Furthermore, during the project execution a multidisciplinary group of experts developed and successfully implemented a set of measures aimed at reducing flat time. Comprehensive planning, an efficient organizational structure, effective communication between all the participants and the introduction of new technologies resulted in the safe and successful construction of 6 horizontal wells with 1500 m long horizontal sections delivered 10% ahead of schedule. Along with the technological progress, it is important to note that during well construction a high level of HSE was achieved with no accidents occurring throughout the entire project.
{"title":"Successful Application of High-Speed Negative-Pulse Telemetry with Compressed Data Transmission Aiming to Increase ROP during Horizontal Wells Drilling in Yuzhno Tambeyskoye Gas Condensate Field","authors":"Andrey Garipov, D. Tur, A. Galimkhanov, Almaz Khalilov, A. Yavorsky, V. Maltsev, V. Pogurets, Aleksey Rybalkin","doi":"10.2118/201869-ms","DOIUrl":"https://doi.org/10.2118/201869-ms","url":null,"abstract":"\u0000 This paper describes the results of efficient cooperation between the Operator, the General Drilling Contractor and the Service Company, who participated in the construction of horizontal wells in Yuzhno-Tambeyskoye gas condensate field.\u0000 This document describes an integrated engineering approach to selection of new technical and technological solutions, which safely achieved all the geological tasks while constructing the wells.\u0000 The key innovations of real-time data transmission from downhole tools, allowed the quality of the information received to be improved which increased the average rate of penetration (ROP) and reduced the well drilling time. Furthermore, during the project execution a multidisciplinary group of experts developed and successfully implemented a set of measures aimed at reducing flat time.\u0000 Comprehensive planning, an efficient organizational structure, effective communication between all the participants and the introduction of new technologies resulted in the safe and successful construction of 6 horizontal wells with 1500 m long horizontal sections delivered 10% ahead of schedule.\u0000 Along with the technological progress, it is important to note that during well construction a high level of HSE was achieved with no accidents occurring throughout the entire project.","PeriodicalId":359083,"journal":{"name":"Day 2 Tue, October 27, 2020","volume":"7 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124971326","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}
Due to the deterioration of petroleum resources in the Republic of Belarus, unconventional reservoirs, which contain hydrocarbons in "shale-like" low-permeable rocks, which include Domanic deposits, become increasingly important. These rocks containing hydrocarbons are both producing oil and at the same time they are not reservoirs in the traditional sense (Varlamov A. I. et al., 2017). The most common technology for developing unconventional reservoirs is drilling horizontal wells with multi-stage hydraulic fracturing. The technological efficiency of drilling such wells will primarily depend on getting into the so - called "sweet spots" - places characterized by the best petrophysical, pyrolytic and geomechanical properties. This ultimately determines the need for a comprehensive study of hydrocarbon deposits in unconventional reservoirs. This article describes the workflow for studying unconventional reservoirs of one of the fields of the Pripyat trough of the Republic of Belarus. Studying these reservoirs was a challenge because due to geological and surface conditions no seismic data was available. The first well logging results showed the absence of significant rock anisotropy detected by standard methods of acoustic logging. This caused difficulties in determining the direction of drilling horizontal wells. There were also insufficient results of core studies of wells, including fully geochemical and geomechanical studies. Carrying out a comprehensive study of promising formations and confirming their oil bearing capacity required making a comprehensive program presented below, which outlined the types of studies that would provide necessary information about lithological, petrophysical, pyrolytic, and geomechanical characteristics of unconventional reservoirs of the field under study. Core studies performed within the integrated study confirmed that the studied sediments are source rocks. At the same time, according to the results of pyrolytic research, it was found that the rocks contain both in-situ hydrocarbons, and the ones which migrated from the underlying formations. The set of geophysical studies carried out on the legacy wells, including logging, hydraulic fracturing and surface seismic monitoring, allowed determining the direction of maximum stress, which eventually allowed determining the direction of drilling horizontal wells. The set of studies described in this article can be used in the study of other unconventional deposits of the Pripyat trough, belonging to the Domanic type.
由于白俄罗斯共和国石油资源的恶化，非常规油藏(在“页岩状”低渗透岩石中含有碳氢化合物，包括Domanic矿床)变得越来越重要。这些含碳氢化合物的岩石既能产油，同时又不是传统意义上的储层(Varlamov a.i. et al.， 2017)。非常规油藏开发最常用的技术是水平井多级水力压裂。钻井此类井的技术效率将主要取决于能否进入所谓的“甜点”，即具有最佳岩石物理、热解和地质力学特性的地方。这最终决定了对非常规油气藏油气沉积进行全面研究的必要性。本文介绍了白俄罗斯普里皮亚季海槽某油田非常规油藏的研究工作流程。由于地质和地面条件，没有地震数据，因此研究这些储层是一项挑战。第一次测井结果表明，标准声波测井方法没有检测到明显的岩石各向异性。这给确定水平井的钻井方向造成了困难。井的岩心研究结果也不充分，包括全面的地球化学和地质力学研究。对有潜力的地层进行全面研究并确认其含油能力需要制定一个综合计划，该计划概述了研究的类型，这些研究将提供有关所研究油田非常规储层的岩性、岩石物理、热解和地质力学特征的必要信息。综合研究中进行的岩心研究证实了所研究的沉积物为烃源岩。同时，根据热解研究结果，发现岩石中既有原位烃，也有从下伏地层迁移而来的烃。对老井进行的一系列地球物理研究，包括测井、水力压裂和地面地震监测，可以确定最大应力的方向，从而最终确定水平井的钻井方向。本文的研究成果可用于普里皮亚季海槽其他多明型非常规矿床的研究。
{"title":"A Comprehensive Study of Unconventional Reservoirs: The Case of Rechitskoe Field Sediments of Rock Units I-III","authors":"A. Kudryashov, P. Povzhik","doi":"10.2118/201820-ms","DOIUrl":"https://doi.org/10.2118/201820-ms","url":null,"abstract":"\u0000 Due to the deterioration of petroleum resources in the Republic of Belarus, unconventional reservoirs, which contain hydrocarbons in \"shale-like\" low-permeable rocks, which include Domanic deposits, become increasingly important. These rocks containing hydrocarbons are both producing oil and at the same time they are not reservoirs in the traditional sense (Varlamov A. I. et al., 2017). The most common technology for developing unconventional reservoirs is drilling horizontal wells with multi-stage hydraulic fracturing. The technological efficiency of drilling such wells will primarily depend on getting into the so - called \"sweet spots\" - places characterized by the best petrophysical, pyrolytic and geomechanical properties. This ultimately determines the need for a comprehensive study of hydrocarbon deposits in unconventional reservoirs.\u0000 This article describes the workflow for studying unconventional reservoirs of one of the fields of the Pripyat trough of the Republic of Belarus. Studying these reservoirs was a challenge because due to geological and surface conditions no seismic data was available. The first well logging results showed the absence of significant rock anisotropy detected by standard methods of acoustic logging. This caused difficulties in determining the direction of drilling horizontal wells. There were also insufficient results of core studies of wells, including fully geochemical and geomechanical studies.\u0000 Carrying out a comprehensive study of promising formations and confirming their oil bearing capacity required making a comprehensive program presented below, which outlined the types of studies that would provide necessary information about lithological, petrophysical, pyrolytic, and geomechanical characteristics of unconventional reservoirs of the field under study.\u0000 Core studies performed within the integrated study confirmed that the studied sediments are source rocks. At the same time, according to the results of pyrolytic research, it was found that the rocks contain both in-situ hydrocarbons, and the ones which migrated from the underlying formations.\u0000 The set of geophysical studies carried out on the legacy wells, including logging, hydraulic fracturing and surface seismic monitoring, allowed determining the direction of maximum stress, which eventually allowed determining the direction of drilling horizontal wells.\u0000 The set of studies described in this article can be used in the study of other unconventional deposits of the Pripyat trough, belonging to the Domanic type.","PeriodicalId":359083,"journal":{"name":"Day 2 Tue, October 27, 2020","volume":"2 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125182282","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}
A. Shakhova, I. Lebedeva, Oleg Valshin, Robert Famiev, D. Marushkin, Roman Savinov, A. Dementyev, A. Shatilov, A. Khakov, A. Shakirova, D. Gaskov, V. Bochkarev, Vladimir Surmin
This paper provides the results of the application of integrated approach to drill the longest extended reach well which has ever been drilled in Odoptu-more field (North Dome) in Sakhalin. Although many extended reach drilling (ERD) wells have been already drilled by the operator in Odoptu-more field, extreme reach wells always require new solutions. Reaching remote reservoirs by applying standard well design of Odoptu-more field was not possible due to high standpipe pressure (SPP) and equivalent circulating density (ECD) in 8 ½-in production section. Engineering study resulted in partial upsize of a well design and change 9 5/8-in casing to liner followed by remaining challenges: 9 5/8-in liner could not be delivered to required depth due to string buckling. Several key technical solutions were implemented in the project thus allowing to deliver the longest well accident-free. Those solutions included well design modification allowing to drill 8 ½-in production section to reach remote reservoirs and 9 5/8-in liner delivery to the required depth using "mud over air" flotation technique for the first time in the project. Having applied integrated approach, the project team broke a new record in drilling the longest well at Odoptu-more field with total measured depth 8699m, ERD ratio 4.89 and Directional Difficulty Index (DDI) of 7.6 (Alistair W. Oag 2000). Drilling extreme reach ERD well unlocked opportunities for the operator to reach and put into the production more distant offshore oil-bearing reservoirs from the land rig without changing existing pad facilities.
{"title":"Integrated Approach Enabled Successful Delivery of the Longest Well on Odoptu-More Field for Russian National Oil Company","authors":"A. Shakhova, I. Lebedeva, Oleg Valshin, Robert Famiev, D. Marushkin, Roman Savinov, A. Dementyev, A. Shatilov, A. Khakov, A. Shakirova, D. Gaskov, V. Bochkarev, Vladimir Surmin","doi":"10.2118/201848-ms","DOIUrl":"https://doi.org/10.2118/201848-ms","url":null,"abstract":"\u0000 This paper provides the results of the application of integrated approach to drill the longest extended reach well which has ever been drilled in Odoptu-more field (North Dome) in Sakhalin.\u0000 Although many extended reach drilling (ERD) wells have been already drilled by the operator in Odoptu-more field, extreme reach wells always require new solutions. Reaching remote reservoirs by applying standard well design of Odoptu-more field was not possible due to high standpipe pressure (SPP) and equivalent circulating density (ECD) in 8 ½-in production section. Engineering study resulted in partial upsize of a well design and change 9 5/8-in casing to liner followed by remaining challenges: 9 5/8-in liner could not be delivered to required depth due to string buckling.\u0000 Several key technical solutions were implemented in the project thus allowing to deliver the longest well accident-free. Those solutions included well design modification allowing to drill 8 ½-in production section to reach remote reservoirs and 9 5/8-in liner delivery to the required depth using \"mud over air\" flotation technique for the first time in the project.\u0000 Having applied integrated approach, the project team broke a new record in drilling the longest well at Odoptu-more field with total measured depth 8699m, ERD ratio 4.89 and Directional Difficulty Index (DDI) of 7.6 (Alistair W. Oag 2000).\u0000 Drilling extreme reach ERD well unlocked opportunities for the operator to reach and put into the production more distant offshore oil-bearing reservoirs from the land rig without changing existing pad facilities.","PeriodicalId":359083,"journal":{"name":"Day 2 Tue, October 27, 2020","volume":"52 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128298300","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}
This study is aimed to detect deviations by using an algorithm fast enough to process data and to elicit information as raw data is being gathered in order to calculate past and current performance parameters and to calculate data-driven future performance. Data manipulation is normally limited to gathering for history matching purposes, but it is not usually processed with data mining techniques to detect performance pattern changes, to discriminate between stable and non-stable periods, to detect changes of fluid density and to perform production forecasting. The algorithm is developed in R language due to the easiness to execute statistical operations with a great deal of data.
{"title":"Data-Driven Analytics for Early Warnings in Reservoir and Well Performance","authors":"R. Canchucaja","doi":"10.2118/201930-ms","DOIUrl":"https://doi.org/10.2118/201930-ms","url":null,"abstract":"\u0000 This study is aimed to detect deviations by using an algorithm fast enough to process data and to elicit information as raw data is being gathered in order to calculate past and current performance parameters and to calculate data-driven future performance. Data manipulation is normally limited to gathering for history matching purposes, but it is not usually processed with data mining techniques to detect performance pattern changes, to discriminate between stable and non-stable periods, to detect changes of fluid density and to perform production forecasting. The algorithm is developed in R language due to the easiness to execute statistical operations with a great deal of data.","PeriodicalId":359083,"journal":{"name":"Day 2 Tue, October 27, 2020","volume":"319 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133366863","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}
A. L. Aleshina, A. Shibaev, O. Philippova, A. Osiptsov, E. Shel, G. Paderin, E. Saifutdinov, A. Churakov, I. Fayzullin
In this paper, the properties of an alternative fluid for hydraulic fracturing (HF) technology based on hydrophobically modified polyacrylamide (HM-PAAm) are studied. HM-PAAm forms gels as a result of cross-linking of polymer chains by hydrophobic domains. Such cross-links are strong enough to impart resistance to temperature, but they can break and recombine under external influences, which makes it possible to restore properties after strong mechanical shear stresses. In the work, the influence of polymer concentration, temperature, and shear rate on the rheological properties of the gels was studied and the conditions for producing gels promising for use in hydraulic fracturing technology were determined.
{"title":"Alternative Fracturing Fluids: Expanding the Field of Possible Applications and Properties of Hydrophobically Modified Polyacrylamide","authors":"A. L. Aleshina, A. Shibaev, O. Philippova, A. Osiptsov, E. Shel, G. Paderin, E. Saifutdinov, A. Churakov, I. Fayzullin","doi":"10.2118/202068-ms","DOIUrl":"https://doi.org/10.2118/202068-ms","url":null,"abstract":"\u0000 In this paper, the properties of an alternative fluid for hydraulic fracturing (HF) technology based on hydrophobically modified polyacrylamide (HM-PAAm) are studied. HM-PAAm forms gels as a result of cross-linking of polymer chains by hydrophobic domains. Such cross-links are strong enough to impart resistance to temperature, but they can break and recombine under external influences, which makes it possible to restore properties after strong mechanical shear stresses. In the work, the influence of polymer concentration, temperature, and shear rate on the rheological properties of the gels was studied and the conditions for producing gels promising for use in hydraulic fracturing technology were determined.","PeriodicalId":359083,"journal":{"name":"Day 2 Tue, October 27, 2020","volume":"215 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126026106","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}
O. Bukov, Artem Basov, D. Lazutkin, D. Kashapov, K. Ovchinnikov, A. Buyanov, A. Drobot, Igor Novikov
Constant growth of commercial hydrocarbon (HC) consumption requires for the oil and gas industry to be involved into exploitation of unusual oil and gas reserves, preventing HC supply shortage on the global market. The fields with conventional reservoirs being actively developed during the last century have a tendency now to reduction of routine parameters of HC production. Now more and more attention is being attracted to tight reserves, which have to be studied in unconventional ways. This article focuses precisely on complex reservoirs, in which reserves are classified as tight. A complex quantitative assessment using several different technologies for long-term monitoring under difficult conditions has shown favorable results.
{"title":"Complex Using of Conventional Production Logging and Indicator Technologies in Tight Oil Reservoir Study","authors":"O. Bukov, Artem Basov, D. Lazutkin, D. Kashapov, K. Ovchinnikov, A. Buyanov, A. Drobot, Igor Novikov","doi":"10.2118/202041-ms","DOIUrl":"https://doi.org/10.2118/202041-ms","url":null,"abstract":"\u0000 Constant growth of commercial hydrocarbon (HC) consumption requires for the oil and gas industry to be involved into exploitation of unusual oil and gas reserves, preventing HC supply shortage on the global market. The fields with conventional reservoirs being actively developed during the last century have a tendency now to reduction of routine parameters of HC production.\u0000 Now more and more attention is being attracted to tight reserves, which have to be studied in unconventional ways. This article focuses precisely on complex reservoirs, in which reserves are classified as tight. A complex quantitative assessment using several different technologies for long-term monitoring under difficult conditions has shown favorable results.","PeriodicalId":359083,"journal":{"name":"Day 2 Tue, October 27, 2020","volume":"46 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121839602","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}
Vertical transverse isotropic (VTI) formations are commonly encountered in sedimentary basins and they are the simplest type of anisotropic formations. However, the inversion of the sonic logging data in such formations is a challenging problem for the case of wells parallel to the axis of symmetry. Most of the conventional processing techniques use only the kinematic characteristics of the wavefield, whereas sufficient information about the anisotropic parameters is contained in the amplitudes of the signal. All the elastic parameters (formation density, compressional and shear wave velocities, Thomsen parameters) cannot be retrieved without rigorous assumptions or additional data (e.g. from deviated borehole). In the present work, we perform a sonic data inversion by using a machine learning approach, more specifically, the convolutional neural network. The main advantage of the method is that the neural network processes the full waveform seismogram taking into account simultaneously the kinematic and the amplitude part of the wavefield. For the network training, a synthetic dataset was generated using the spectral element method. The results of the work demonstrate the feasibility of the method, when a seismogram is fed to the input of the neural network and elastic parameters are given as the output.
{"title":"Thomsen Parameters Determination from Synthetic Sonic Logging Data for VTI Formation Using a Convolutional Neural Network","authors":"M. Bazulin, D. Sabitov, M. Charara","doi":"10.2118/201932-ms","DOIUrl":"https://doi.org/10.2118/201932-ms","url":null,"abstract":"\u0000 Vertical transverse isotropic (VTI) formations are commonly encountered in sedimentary basins and they are the simplest type of anisotropic formations. However, the inversion of the sonic logging data in such formations is a challenging problem for the case of wells parallel to the axis of symmetry. Most of the conventional processing techniques use only the kinematic characteristics of the wavefield, whereas sufficient information about the anisotropic parameters is contained in the amplitudes of the signal. All the elastic parameters (formation density, compressional and shear wave velocities, Thomsen parameters) cannot be retrieved without rigorous assumptions or additional data (e.g. from deviated borehole). In the present work, we perform a sonic data inversion by using a machine learning approach, more specifically, the convolutional neural network. The main advantage of the method is that the neural network processes the full waveform seismogram taking into account simultaneously the kinematic and the amplitude part of the wavefield. For the network training, a synthetic dataset was generated using the spectral element method. The results of the work demonstrate the feasibility of the method, when a seismogram is fed to the input of the neural network and elastic parameters are given as the output.","PeriodicalId":359083,"journal":{"name":"Day 2 Tue, October 27, 2020","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130369079","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}
K. V. Toropetsky, G. Borisov, M. Samoilov, I. Eltsov
The established practice of geomechanical testing includes the procedures of core sampling and marking, as well as core plug drilling out and testing. The key challenge is that a selection of core plugs is physically or economically limited. The classical core analysis offers a limited and discrete data set. Along with that, the tests carried out on a set of core plugs are dependent upon the core quality and the accuracy of selection of the core plugs sharing identical properties. These constraints impair accuracy and reliability of geomechanical models. This paper describes controlled core scratching (CST) as a method of geomechanical testing of full-size cores. Physically, the CST method is based on resistance measurements of the of full-size cores to scratching. Depending on the cutter penetration depth and the core sample scratching rate, the force characterizes unconfined compressive strength (UCS) and/or fracture resistance of the rock. The principal CST advantage is that it provides accurate and diverse continuous geomechanical rock properties. The application of the CST method enhances comprehensive core analysis accuracy, synthetic physical & mechanical parameters reliability and, therefore, geomechanical modeling precision. In practice, the CST method applied in conjunction with the classical geomechnical core analysis enhances the quality of drilling, completion, frac'ing, and field development support in general. This paper presents a comparative study of geomechanical models that incorporate synthetic curves for unconfined compressive strength (UCS), Brazilian tensile strength (BTS) and cohesion strength (CS), derived from the CST and well logging data, using a well that is drilled through halocarbonates and clastics as an example. The comparative study of the CST-based and log-based geomechanical models demonstrated that the CST-based model outputs robust correlations and detailed distinctive curves of physical & mechanical properties and clear stratification boundaries.
{"title":"Advanced Method of Controlled Core Scratching as a Source of Geomechanical Data","authors":"K. V. Toropetsky, G. Borisov, M. Samoilov, I. Eltsov","doi":"10.2118/201984-ms","DOIUrl":"https://doi.org/10.2118/201984-ms","url":null,"abstract":"\u0000 The established practice of geomechanical testing includes the procedures of core sampling and marking, as well as core plug drilling out and testing. The key challenge is that a selection of core plugs is physically or economically limited. The classical core analysis offers a limited and discrete data set. Along with that, the tests carried out on a set of core plugs are dependent upon the core quality and the accuracy of selection of the core plugs sharing identical properties. These constraints impair accuracy and reliability of geomechanical models.\u0000 This paper describes controlled core scratching (CST) as a method of geomechanical testing of full-size cores. Physically, the CST method is based on resistance measurements of the of full-size cores to scratching. Depending on the cutter penetration depth and the core sample scratching rate, the force characterizes unconfined compressive strength (UCS) and/or fracture resistance of the rock.\u0000 The principal CST advantage is that it provides accurate and diverse continuous geomechanical rock properties. The application of the CST method enhances comprehensive core analysis accuracy, synthetic physical & mechanical parameters reliability and, therefore, geomechanical modeling precision. In practice, the CST method applied in conjunction with the classical geomechnical core analysis enhances the quality of drilling, completion, frac'ing, and field development support in general.\u0000 This paper presents a comparative study of geomechanical models that incorporate synthetic curves for unconfined compressive strength (UCS), Brazilian tensile strength (BTS) and cohesion strength (CS), derived from the CST and well logging data, using a well that is drilled through halocarbonates and clastics as an example. The comparative study of the CST-based and log-based geomechanical models demonstrated that the CST-based model outputs robust correlations and detailed distinctive curves of physical & mechanical properties and clear stratification boundaries.","PeriodicalId":359083,"journal":{"name":"Day 2 Tue, October 27, 2020","volume":"54 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125942299","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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