M. Golenkin, D. Eliseev, A. Zemchikhin, A. Borisenko, Akhmat Sakhadinovich Atabiyev, E. Sorokin, Yevgeniy Orestovich Mikitin, Aidar Biktimirovich Khusainov, Andrey Valeryevich Liplyanin, Andrey Valeryevich Sidorov, Rustem Talgatovich Bashirov, Sergey Anatolyevich Goryachev
The paper describes the results of the first multistage hydraulic fracturing operations in Russia on the Caspian Sea shelf in the gas condensate and oil deposits of the Aptian formation of V. Filanovsky field. In addition to the small productive formation depth, long horizontal sections with a complex trajectory and high collapse gradients due to large zenith angles when passing the Albian and Aptian deposits of poorly consolidated sandstones are an additional challenge for choosing a multistage hydraulic fracturing assembly. The above features require the use of modern sand control screens with enhanced frac sleeves. A design was developed which includes frac sleeves and sand control screens that can withstand multiple cycles of hydraulic impact during hydraulic fracturing, as well as many opening/closing cycles. A seawater-based frac fluid system was applied. The frac fleet was located on a pontoon, the coiled tubing – on a platform. For the first time in Russia, a 2-5/8 inch coiled tubing with a complex-type friction reducing system was used to switch coupling/sleeves in conditions of very long horizontal sections, complex trajectories, and high friction coefficients. The minimum distances between the screen's sliding sleeves and frac sleeves did not prevent from performing manipulations in complex environment. For well cleaning, the frac assemblies of reverse rotary-pulse and rotary-directional types were used. At the first stage of the project, the development of an optimal method of well completion was successfully implemented. Due to the close interaction of the operating company, service company, and science & engineering team of the operator, for the first time in Russia the design of downhole equipment with the use of advanced technologies of sand control screens, frac sleeves was presented. This solution has proved its effectiveness – the downhole equipment has retained its operational properties after a long period of well operation and further in the process of hydraulic fracturing. At the second stage of the project, 32 MSHF operations were performed at four wells. To reduce nonproductive time and operational risks, a satellite communication complex was additionally deployed on the pontoon to join the engineering centers of Astrakhan, Moscow, and Houston. After finishing the well development, the design indicators for formation fluid rates were achieved, which proved the effectiveness of the stimulation of the field's target objects – this opens great prospects for further development of low-permeability reservoirs at offshore sites in the Caspian Sea. The successful project implementation and the achievement of the design values of oil flow rates has expanded the possibilities of commercial operation of the low-permeable Aptian formation, complicated by the presence of a gas cap and underlying water. A solution was presented for working in extended horizontal well sections with 2-5/8 inch coiled tubing together with a compl
{"title":"First Multistage Hydraulic Fracturing in Russian Offshore: Integrated Approach to Completion and Stimulation of Apt Deposits of V.Filanovsky Field","authors":"M. Golenkin, D. Eliseev, A. Zemchikhin, A. Borisenko, Akhmat Sakhadinovich Atabiyev, E. Sorokin, Yevgeniy Orestovich Mikitin, Aidar Biktimirovich Khusainov, Andrey Valeryevich Liplyanin, Andrey Valeryevich Sidorov, Rustem Talgatovich Bashirov, Sergey Anatolyevich Goryachev","doi":"10.2118/206633-ms","DOIUrl":"https://doi.org/10.2118/206633-ms","url":null,"abstract":"\u0000 The paper describes the results of the first multistage hydraulic fracturing operations in Russia on the Caspian Sea shelf in the gas condensate and oil deposits of the Aptian formation of V. Filanovsky field. In addition to the small productive formation depth, long horizontal sections with a complex trajectory and high collapse gradients due to large zenith angles when passing the Albian and Aptian deposits of poorly consolidated sandstones are an additional challenge for choosing a multistage hydraulic fracturing assembly. The above features require the use of modern sand control screens with enhanced frac sleeves.\u0000 A design was developed which includes frac sleeves and sand control screens that can withstand multiple cycles of hydraulic impact during hydraulic fracturing, as well as many opening/closing cycles. A seawater-based frac fluid system was applied.\u0000 The frac fleet was located on a pontoon, the coiled tubing – on a platform. For the first time in Russia, a 2-5/8 inch coiled tubing with a complex-type friction reducing system was used to switch coupling/sleeves in conditions of very long horizontal sections, complex trajectories, and high friction coefficients. The minimum distances between the screen's sliding sleeves and frac sleeves did not prevent from performing manipulations in complex environment. For well cleaning, the frac assemblies of reverse rotary-pulse and rotary-directional types were used.\u0000 At the first stage of the project, the development of an optimal method of well completion was successfully implemented. Due to the close interaction of the operating company, service company, and science & engineering team of the operator, for the first time in Russia the design of downhole equipment with the use of advanced technologies of sand control screens, frac sleeves was presented. This solution has proved its effectiveness – the downhole equipment has retained its operational properties after a long period of well operation and further in the process of hydraulic fracturing.\u0000 At the second stage of the project, 32 MSHF operations were performed at four wells. To reduce nonproductive time and operational risks, a satellite communication complex was additionally deployed on the pontoon to join the engineering centers of Astrakhan, Moscow, and Houston. After finishing the well development, the design indicators for formation fluid rates were achieved, which proved the effectiveness of the stimulation of the field's target objects – this opens great prospects for further development of low-permeability reservoirs at offshore sites in the Caspian Sea.\u0000 The successful project implementation and the achievement of the design values of oil flow rates has expanded the possibilities of commercial operation of the low-permeable Aptian formation, complicated by the presence of a gas cap and underlying water.\u0000 A solution was presented for working in extended horizontal well sections with 2-5/8 inch coiled tubing together with a compl","PeriodicalId":11017,"journal":{"name":"Day 2 Wed, October 13, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88635886","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}
Geomechanical modeling is an integral part of the oil and gas industry and is used in all life cycles of the field - monitoring and improving the efficiency of well construction, choosing a completion system, modeling hydraulic fracturing processes, modeling development processes taking into account changes in the stress state of the reservoir, taking into account the fault, salt tectonics, control over the development of the reservoir, control of subsidence of the earth's surface. The success of geomechanical modeling directly depends on the quantity and quality of input data. In contrast to the geological and hydrodynamic models, in geomechanics there is still no unified approach and algorithm for quantifying the model error. The quality of the geomechanical model is defined as "satisfactory" / "not satisfactory" and "confirmed by actual data" / "not confirmed by actual data". In a series of articles on "Metrological support of a geomechanical model", the authors show an algorithm for a quantitative assessment of the error of a geomechanical model. The proposed algorithm takes into account the measurement error (in the well and in the laboratory), the quality of logging data, direct measurements or reconstructed measurements, the tightness of correlations (both for the results of core studies and for the reconstruction of missing logging data), the calculation of the uncertainty taking into account the calibration information. This paper describes a generalized algorithm for quantifying the error of a geomechanical model, presented in previous articles, and provides a method for quantifying calculate the uncertainty, taking into account calibration information, such as measurements of horizontal stresses, core studies in laboratory conditions.
{"title":"Metrology and Standardization in Geomechanical Modeling - A Quantitative Assessment of Uncertainty Window Based on Calibration Data","authors":"O. Tatur, Y. Petrakov, Alexey Sobolev","doi":"10.2118/206564-ms","DOIUrl":"https://doi.org/10.2118/206564-ms","url":null,"abstract":"\u0000 Geomechanical modeling is an integral part of the oil and gas industry and is used in all life cycles of the field - monitoring and improving the efficiency of well construction, choosing a completion system, modeling hydraulic fracturing processes, modeling development processes taking into account changes in the stress state of the reservoir, taking into account the fault, salt tectonics, control over the development of the reservoir, control of subsidence of the earth's surface. The success of geomechanical modeling directly depends on the quantity and quality of input data. In contrast to the geological and hydrodynamic models, in geomechanics there is still no unified approach and algorithm for quantifying the model error. The quality of the geomechanical model is defined as \"satisfactory\" / \"not satisfactory\" and \"confirmed by actual data\" / \"not confirmed by actual data\". In a series of articles on \"Metrological support of a geomechanical model\", the authors show an algorithm for a quantitative assessment of the error of a geomechanical model. The proposed algorithm takes into account the measurement error (in the well and in the laboratory), the quality of logging data, direct measurements or reconstructed measurements, the tightness of correlations (both for the results of core studies and for the reconstruction of missing logging data), the calculation of the uncertainty taking into account the calibration information.\u0000 This paper describes a generalized algorithm for quantifying the error of a geomechanical model, presented in previous articles, and provides a method for quantifying calculate the uncertainty, taking into account calibration information, such as measurements of horizontal stresses, core studies in laboratory conditions.","PeriodicalId":11017,"journal":{"name":"Day 2 Wed, October 13, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89624261","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}
Ihar Stsiapankin, Andrei Khaletski, Raman Hutman, Viktar Tkachou
It was developed the method for determining the strength of material without breaking the test sample. The essence of the method is to determine the strength characteristics of the rock by pressing into the variable cross-section indenter. The practical significance lies in the possibility of performing an express analysis of the strength of rocks on small-sized samples - 3 mm or more, for example, using the particles of landslide cuttings from unstable intervals when drilling wells; there is no need for the preparation of reference material; the simplicity and availability of the equipment used and high accuracy of the results obtained is also important. The developed method has no analogues and is patented in the patent offices of the Republic of Belarus and the Russian Federation.
{"title":"On the Use of Indentation for Studying Rock Properties","authors":"Ihar Stsiapankin, Andrei Khaletski, Raman Hutman, Viktar Tkachou","doi":"10.2118/206560-ms","DOIUrl":"https://doi.org/10.2118/206560-ms","url":null,"abstract":"\u0000 It was developed the method for determining the strength of material without breaking the test sample. The essence of the method is to determine the strength characteristics of the rock by pressing into the variable cross-section indenter. The practical significance lies in the possibility of performing an express analysis of the strength of rocks on small-sized samples - 3 mm or more, for example, using the particles of landslide cuttings from unstable intervals when drilling wells; there is no need for the preparation of reference material; the simplicity and availability of the equipment used and high accuracy of the results obtained is also important. The developed method has no analogues and is patented in the patent offices of the Republic of Belarus and the Russian Federation.","PeriodicalId":11017,"journal":{"name":"Day 2 Wed, October 13, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76500917","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}
D. Gospodarev, I. Lymar, A. Rakutko, A. Antuseva, D. Tkachev
Nowadays, chemical EOR methods are becoming more and more relevant, among which the alkali-surfactant-polymer flooding is of particular interest. The efficiency of this technology largely depends on the correct choice of the components of chemical formulation, which should be based on a set of laboratory experiments carried out in a given sequence. This paper presents a methodological approach to laboratory studies in order to develop an optimal surfactant-polymer formulation, taking into account the geological and physical characteristics of the target field and the properties of reservoir fluids. The experimental part of the research work was carried out in several stages, involving the analysis of the physicochemical characteristics of reservoir oil, the screening studies of surfactant and polymer samples, as well as a series of coreflood tests with a selected chemical formulation on the terrigenous reservoir models. During screening studies, the solubility and compatibility of the chemical components, the phase behavior of surfactant solutions with oil at different salinity values and water-oil ratios, static adsorption of chemicals on the rock and their thermal stability at reservoir temperature were investigated. Optimization of the chemical formulation was based on the results of IFT measurements of the surfactant solutions and rheological studies of the polymer solutions. At the stage of coreflood tests, physical simulation of the surfactant-polymer flooding was carried out on reservoir models using natural core material in order to optimize the composition and slug size of the developed chemical formulation. The obtained results of the displacement experiment were matched by numerical 1D simulation. Based on the results of the studies performed, an effective surfactant-polymer formulation has been designed, which provides the ultra-low IFT (2.8·10−4 mN/m) values and the ability to form stable middle-phase microemulsions when interacting with oil. The findings of thermal stability and static adsorption experiments confirmed a feasibility of selected chemicals for practical application. Within the framework of the study, the key technical parameters of proposed formulation were determined, which are required for up-scaled simulation study of the chemical flooding process at pilot site.
{"title":"Design of Laboratory Studies to Develop the Chemical Formulation for Surfactant-Polymer Flooding","authors":"D. Gospodarev, I. Lymar, A. Rakutko, A. Antuseva, D. Tkachev","doi":"10.2118/206436-ms","DOIUrl":"https://doi.org/10.2118/206436-ms","url":null,"abstract":"\u0000 Nowadays, chemical EOR methods are becoming more and more relevant, among which the alkali-surfactant-polymer flooding is of particular interest. The efficiency of this technology largely depends on the correct choice of the components of chemical formulation, which should be based on a set of laboratory experiments carried out in a given sequence.\u0000 This paper presents a methodological approach to laboratory studies in order to develop an optimal surfactant-polymer formulation, taking into account the geological and physical characteristics of the target field and the properties of reservoir fluids.\u0000 The experimental part of the research work was carried out in several stages, involving the analysis of the physicochemical characteristics of reservoir oil, the screening studies of surfactant and polymer samples, as well as a series of coreflood tests with a selected chemical formulation on the terrigenous reservoir models.\u0000 During screening studies, the solubility and compatibility of the chemical components, the phase behavior of surfactant solutions with oil at different salinity values and water-oil ratios, static adsorption of chemicals on the rock and their thermal stability at reservoir temperature were investigated. Optimization of the chemical formulation was based on the results of IFT measurements of the surfactant solutions and rheological studies of the polymer solutions.\u0000 At the stage of coreflood tests, physical simulation of the surfactant-polymer flooding was carried out on reservoir models using natural core material in order to optimize the composition and slug size of the developed chemical formulation. The obtained results of the displacement experiment were matched by numerical 1D simulation.\u0000 Based on the results of the studies performed, an effective surfactant-polymer formulation has been designed, which provides the ultra-low IFT (2.8·10−4 mN/m) values and the ability to form stable middle-phase microemulsions when interacting with oil. The findings of thermal stability and static adsorption experiments confirmed a feasibility of selected chemicals for practical application. Within the framework of the study, the key technical parameters of proposed formulation were determined, which are required for up-scaled simulation study of the chemical flooding process at pilot site.","PeriodicalId":11017,"journal":{"name":"Day 2 Wed, October 13, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76684761","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. Aslanyan, A. Y. Popov, I. Zhdanov, E.S. Pakhomov, Nikolay Petrovich Ibryaev, Maksim Aleksandrovich Kuznetsov, V. Krichevsky, M. Garnyshev, R. Guss
The paper presents the results of a study project of 60+ well block of the large (> 1,000 wells) mature (30 year old) oilfield in Western Siberia with objective to localise and characterize residual recoverable reserves and propose the optimal economic scenario for further depletion. Low permeability, heterogeneous reserve structure along the cross-section, numerous induced hydraulic fractures in producing wells and numerous spontaneous fractures in injecting wells with dynamic behavior, aggravated by numerous behind-the-casing crossflows in almost every well have resulted in a very complex conditions of remaining reserves. The conventional methods of production analysis and surveillance (well testing and production logging) do not provide a consistent picture of the current distribution and conditions of the remaining reserves and required a deeper and more complex analysis. Development Opportunities Management workflow was chosen for this particular holistic study, which includes a set of interconnected studies, field surveillance, geological and flow modelling and culminated in field development planning based on the digital asset twin. (Ganiev, B., 2021) Digital asset twin was constructed based on results of this workflow with a full-range economical model, flow simulation over the thoroughly calibrated fine-grid 3D dynamic model and production complication model (dynamic behavior of the fractures and behind-casing channeling). The 3D model has been calibrated on results of the cross-well pressure-pulse surveillance, reservoir-oriented production logging and was validated by the results of the drilling of the transition wells. The digital asset twin was used to find the optimal investment scenario based on multivariate calculations with the help of digital assistants. Due to simplicity of the user interface and client-server design, the digital twin was made available for various corporate engineers and managers without any modelling skills to play around with their own ideas on possible production/investment scenarios which gave another level of validation of the ultimate field development plan. All activities carried out within the digital twin automatically generate a complete package of investment metrics (NPV, PI, IRR, MIRR, Cash Flow and many correlation graphs) to assess the economic efficiency of each package and select the most appropriate solution for further ultimate choice. The approved scenario was based around drilling 6 producing side-tracks in specific locations/trajectories, performing workovers on specific offset injectors and re-scheduling of the production/injection rates in all block wells. The results of the field development's activities implementation will be the subject of a future publication.
{"title":"Localisation and Recovery Planning of the Remaining Hydrocarbon Reserves","authors":"A. Aslanyan, A. Y. Popov, I. Zhdanov, E.S. Pakhomov, Nikolay Petrovich Ibryaev, Maksim Aleksandrovich Kuznetsov, V. Krichevsky, M. Garnyshev, R. Guss","doi":"10.2118/206494-ms","DOIUrl":"https://doi.org/10.2118/206494-ms","url":null,"abstract":"\u0000 The paper presents the results of a study project of 60+ well block of the large (> 1,000 wells) mature (30 year old) oilfield in Western Siberia with objective to localise and characterize residual recoverable reserves and propose the optimal economic scenario for further depletion.\u0000 Low permeability, heterogeneous reserve structure along the cross-section, numerous induced hydraulic fractures in producing wells and numerous spontaneous fractures in injecting wells with dynamic behavior, aggravated by numerous behind-the-casing crossflows in almost every well have resulted in a very complex conditions of remaining reserves.\u0000 The conventional methods of production analysis and surveillance (well testing and production logging) do not provide a consistent picture of the current distribution and conditions of the remaining reserves and required a deeper and more complex analysis.\u0000 Development Opportunities Management workflow was chosen for this particular holistic study, which includes a set of interconnected studies, field surveillance, geological and flow modelling and culminated in field development planning based on the digital asset twin. (Ganiev, B., 2021)\u0000 Digital asset twin was constructed based on results of this workflow with a full-range economical model, flow simulation over the thoroughly calibrated fine-grid 3D dynamic model and production complication model (dynamic behavior of the fractures and behind-casing channeling).\u0000 The 3D model has been calibrated on results of the cross-well pressure-pulse surveillance, reservoir-oriented production logging and was validated by the results of the drilling of the transition wells.\u0000 The digital asset twin was used to find the optimal investment scenario based on multivariate calculations with the help of digital assistants.\u0000 Due to simplicity of the user interface and client-server design, the digital twin was made available for various corporate engineers and managers without any modelling skills to play around with their own ideas on possible production/investment scenarios which gave another level of validation of the ultimate field development plan.\u0000 All activities carried out within the digital twin automatically generate a complete package of investment metrics (NPV, PI, IRR, MIRR, Cash Flow and many correlation graphs) to assess the economic efficiency of each package and select the most appropriate solution for further ultimate choice.\u0000 The approved scenario was based around drilling 6 producing side-tracks in specific locations/trajectories, performing workovers on specific offset injectors and re-scheduling of the production/injection rates in all block wells.\u0000 The results of the field development's activities implementation will be the subject of a future publication.","PeriodicalId":11017,"journal":{"name":"Day 2 Wed, October 13, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87865060","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}
D. Krivolapov, I. Masalida, A. Polyarush, Vyacheslav Visloguzov, A. Averkin, Artem Rudykh, P. Ivanov
This paper discusses the successful implementation of PMCD (Pressurized Mud Cap Drilling) technology at Severo – Danilovskoe oil and gas field (SDO) located in the Irkutsk region. The abnormally high-pressure reservoir B1 and the abnormally low-pressure reservoir B5 are the target layers in this field. Wells drilling at SDO is accompanied with simultaneous mud losses and inflows conditions, especially if the strata B1 is being penetrated. Pumping lost circulation materials (LCM) and cement plugs do not solve lost circulation complications which subsequently lead to oil and gas inflows. As a result, most of such wells are getting abandoned. It was assumed that complications in this formation occurs due to the narrow safe pressures’ operating window (ECD window), therefore, the managed pressure drilling technology (MPD) was initially used as a solution to this problem. However, after the penetration of the abnormally high formation pressure B1 horizon with a pore pressure gradient of 1.86 g/cm3 it was found that there is no operating window. In this regard, there were simultaneous mud losses and oil and gas inflows during the circulation. The well was gradually replaced by oil and gas, regardless of the applied surface back pressure value in the MPD system. The mixing of the mud and reservoir fluid was accompanied by catastrophic contamination. As a result, the drilling mud became non - flowing plugging both the mud cleaning system and the gas separator. On the other hand, the plugging of the B1 formation with LCM did not bring any positive results. Bullheading the well followed by drilling with applied surface back pressure and partial mud losses gave only a temporary result and required a large amount of resources. An implementation of PMCD technology instead of MPD has been proposed as an alternative solution to the problem. This technology made it possible to drill the well to the designed depth (2904 - 3010 m interval). For tripping operations, as well as the subsequent running of the production liner it was necessary to develop an integrated plan for well killing and completion in extreme instability conditions. As a result of various killing techniques application, it became possible to achieve the stability of the well for 1 hour. Oil and gas inflows inevitably occurred when the 1 hour lasted. Based on these conditions, the tripping and well completion process was adapted, which in the end made it possible to successfully complete the well, run the liner and activate the hanger in the abnormally high-pressure reservoir.
{"title":"Successful Implementation of the PMCD Technology for Drilling and Completing the Well in Incompatible Conditions at Severo – Danilovskoe Oil & Gas Field","authors":"D. Krivolapov, I. Masalida, A. Polyarush, Vyacheslav Visloguzov, A. Averkin, Artem Rudykh, P. Ivanov","doi":"10.2118/206456-ms","DOIUrl":"https://doi.org/10.2118/206456-ms","url":null,"abstract":"\u0000 This paper discusses the successful implementation of PMCD (Pressurized Mud Cap Drilling) technology at Severo – Danilovskoe oil and gas field (SDO) located in the Irkutsk region. The abnormally high-pressure reservoir B1 and the abnormally low-pressure reservoir B5 are the target layers in this field. Wells drilling at SDO is accompanied with simultaneous mud losses and inflows conditions, especially if the strata B1 is being penetrated. Pumping lost circulation materials (LCM) and cement plugs do not solve lost circulation complications which subsequently lead to oil and gas inflows. As a result, most of such wells are getting abandoned.\u0000 It was assumed that complications in this formation occurs due to the narrow safe pressures’ operating window (ECD window), therefore, the managed pressure drilling technology (MPD) was initially used as a solution to this problem. However, after the penetration of the abnormally high formation pressure B1 horizon with a pore pressure gradient of 1.86 g/cm3 it was found that there is no operating window. In this regard, there were simultaneous mud losses and oil and gas inflows during the circulation. The well was gradually replaced by oil and gas, regardless of the applied surface back pressure value in the MPD system. The mixing of the mud and reservoir fluid was accompanied by catastrophic contamination. As a result, the drilling mud became non - flowing plugging both the mud cleaning system and the gas separator. On the other hand, the plugging of the B1 formation with LCM did not bring any positive results. Bullheading the well followed by drilling with applied surface back pressure and partial mud losses gave only a temporary result and required a large amount of resources.\u0000 An implementation of PMCD technology instead of MPD has been proposed as an alternative solution to the problem. This technology made it possible to drill the well to the designed depth (2904 - 3010 m interval). For tripping operations, as well as the subsequent running of the production liner it was necessary to develop an integrated plan for well killing and completion in extreme instability conditions. As a result of various killing techniques application, it became possible to achieve the stability of the well for 1 hour. Oil and gas inflows inevitably occurred when the 1 hour lasted. Based on these conditions, the tripping and well completion process was adapted, which in the end made it possible to successfully complete the well, run the liner and activate the hanger in the abnormally high-pressure reservoir.","PeriodicalId":11017,"journal":{"name":"Day 2 Wed, October 13, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78888557","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. Ushakova, E. Mukhina, A. Scerbacova, A. Turakhanov, D. Bakulin, A. Cheremisin, A. Kasyanenko
The article describes the development aimed at a comprehensive study for enhanced oil recovery methods (EOR) of the Bazhenov shale oil formation. Potentially effective technologies for low-permeable reservoirs are under consideration: injection of associated petroleum gas in the mode of miscible displacement to recover light oil; injection of the surfactants water solutions, to separate sorbed hydrocarbons from the rock and change core wettability; and heating technologies to convert solid hydrocarbons into liquid and gaseous, and recover. The project explore potentially effective EOR technologies and their influence on the various types of hydrocarbons of the shale Bazhenov formation: mobile oil in closed pores, sorbed and solid (kerogen) hydrocarbons. Experimental studies were carried out: the selection of the gases composition, the selection of surfactant compositions, the study of the possibility of thermal exposure by over-heated water injection. The project is currently at the stage of determining the effectiveness of each method, selecting a technology for specific field conditions and identifying which hydrocarbon resources each method is aimed at extracting.
{"title":"A Comprehensive Project of Thermal, Gas and Chemical EOR Method Application for Bazhenov Shale Formation","authors":"A. Ushakova, E. Mukhina, A. Scerbacova, A. Turakhanov, D. Bakulin, A. Cheremisin, A. Kasyanenko","doi":"10.2118/206424-ms","DOIUrl":"https://doi.org/10.2118/206424-ms","url":null,"abstract":"\u0000 The article describes the development aimed at a comprehensive study for enhanced oil recovery methods (EOR) of the Bazhenov shale oil formation. Potentially effective technologies for low-permeable reservoirs are under consideration: injection of associated petroleum gas in the mode of miscible displacement to recover light oil; injection of the surfactants water solutions, to separate sorbed hydrocarbons from the rock and change core wettability; and heating technologies to convert solid hydrocarbons into liquid and gaseous, and recover.\u0000 The project explore potentially effective EOR technologies and their influence on the various types of hydrocarbons of the shale Bazhenov formation: mobile oil in closed pores, sorbed and solid (kerogen) hydrocarbons. Experimental studies were carried out: the selection of the gases composition, the selection of surfactant compositions, the study of the possibility of thermal exposure by over-heated water injection. The project is currently at the stage of determining the effectiveness of each method, selecting a technology for specific field conditions and identifying which hydrocarbon resources each method is aimed at extracting.","PeriodicalId":11017,"journal":{"name":"Day 2 Wed, October 13, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77077634","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}
M. Dulkarnaev, Y. Kotenev, S. Sultanov, A. V. Chibisov, Daria Yurievna Chudinova, A. Katashov, E. Malyavko, A. Buyanov, Ekaterina Evgenievna Semyonova, O. Gorbokonenko
In pursuit of efficient oil and gas field development, including hard-to-recover reserves, the key objective is to develop and provide the rationale for oil recovery improvement recommendations. This paper presents the results of the use of the workflow process for optimized field development at two field clusters of the Yuzhno-Vyintoiskoye field using geological and reservoir modelling and dynamic marker-based flow production surveillance in producing horizontal wells. The target reservoir of the Yuzhno-Vyntoiskoye deposit is represented by a series of wedge-shaped Neocomian sandstones. Sand bodies typically have a complex geological structure, lateral continuity and a complex distribution of reservoir rocks. Reservoir beds are characterised by low thickness and permeability. The pay zone of the section is a highly heterogeneous formation, which is manifested through vertical variability of the lithological type of reservoir rocks, lithological substitutions, and the high clay content of reservoirs. The target reservoir of the Yuzhno-Vyintoiskoye field is marked by an extensive water-oil zone with highly variable water saturation. According to paleogeographic data, the reservoir was formed in shallow marine settings. Sand deposits are represented by regressive cyclites that are typical for the progressing coastal shallow water (Dulkarnaev et al., 2020). Currently, the reservoir is in production increase cycle. That is why an integrated approach is used in this work to provide a further rationale and creation of the starting points of the reservoir pressure maintenance system impact at new drilling fields to improve oil recovery and secure sustainable oil production and the reserve development rate under high uncertainty.
在追求高效油气田开发(包括难以开采的储量)的过程中，关键目标是开发并提供提高采收率的基本原理建议。本文介绍了在Yuzhno-Vyintoiskoye油田的两个油田群中，利用地质和油藏建模以及基于动态标记的水平井生产流量监测，使用工作流流程优化油田开发的结果。豫中- vyntoiskoye矿床的目标储层为一系列楔形新新统砂岩。砂体通常具有复杂的地质构造、横向连续性和复杂的储层分布。储层具有低厚度、低渗透率的特点。该剖面产层为高度非均质地层，表现为储层岩性类型的垂向变异性、岩性替代、储层粘土含量高。Yuzhno-Vyintoiskoye油田的目标储层具有广泛的含水含油带，含水饱和度变化很大。古地理资料表明，该储层形成于浅海环境。砂沉积以退化旋回体为代表，这是沿海浅水的典型特征(Dulkarnaev et al.， 2020)。目前，该油藏正处于增产周期。这就是为什么在这项工作中使用了一种综合方法，为新钻井油田的油藏压力维护系统影响提供进一步的理论基础和创建起点，以提高石油采收率，确保高不确定性下的可持续石油生产和储量开发速度。
{"title":"Geological and Field Feasibility Study of Field Development Management Using Marker-Based Production Profiling Surveillance in Horizontal Wells: The Case Study of the Yuzhno-Vyintoiskoye Field","authors":"M. Dulkarnaev, Y. Kotenev, S. Sultanov, A. V. Chibisov, Daria Yurievna Chudinova, A. Katashov, E. Malyavko, A. Buyanov, Ekaterina Evgenievna Semyonova, O. Gorbokonenko","doi":"10.2118/206509-ms","DOIUrl":"https://doi.org/10.2118/206509-ms","url":null,"abstract":"In pursuit of efficient oil and gas field development, including hard-to-recover reserves, the key objective is to develop and provide the rationale for oil recovery improvement recommendations. This paper presents the results of the use of the workflow process for optimized field development at two field clusters of the Yuzhno-Vyintoiskoye field using geological and reservoir modelling and dynamic marker-based flow production surveillance in producing horizontal wells.\u0000 The target reservoir of the Yuzhno-Vyntoiskoye deposit is represented by a series of wedge-shaped Neocomian sandstones. Sand bodies typically have a complex geological structure, lateral continuity and a complex distribution of reservoir rocks. Reservoir beds are characterised by low thickness and permeability. The pay zone of the section is a highly heterogeneous formation, which is manifested through vertical variability of the lithological type of reservoir rocks, lithological substitutions, and the high clay content of reservoirs. The target reservoir of the Yuzhno-Vyintoiskoye field is marked by an extensive water-oil zone with highly variable water saturation. According to paleogeographic data, the reservoir was formed in shallow marine settings. Sand deposits are represented by regressive cyclites that are typical for the progressing coastal shallow water (Dulkarnaev et al., 2020).\u0000 Currently, the reservoir is in production increase cycle. That is why an integrated approach is used in this work to provide a further rationale and creation of the starting points of the reservoir pressure maintenance system impact at new drilling fields to improve oil recovery and secure sustainable oil production and the reserve development rate under high uncertainty.","PeriodicalId":11017,"journal":{"name":"Day 2 Wed, October 13, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77171627","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}
E. Korelskiy, Y. Petrakov, Alexey Sobolev, A. Ablaev, D. Mylnikov, D. Melnichuk
During recent years reduction of carbon dioxide emission driving development of different technologies for CO2 capturing and utilization. Carbon dioxide injection in underground reservoirs is on of effective methods for storage or utilization as enhanced oil recovery agent. Selection of the potential reservoir for CO2 injection is critically important for long term gas storage. In this paper demonstrated software solutions and workflows for modelling of geomechanical modelling of CO2 injection. Injection of CO2 into the reservoir entails a change in reservoir pressure and a change in reservoir temperature. In turn, the stress-strain state of the massif changes, which can lead to the destruction of the reservoir rock and host rocks, reactivation of faults, and, as a consequence, the loss of the integrity of the seal and uncontrolled interstratal crossflows. This paper will describe an example of choosing a reservoir for CO2 injection based on the study of the stress-strain state of the rock mass and its changes due to gas injection. Currently, there are various approaches to CO2 recovery into the reservoir, including injection into depleted gas reservoirs, aquifers and oil reservoirs for the purpose of enhanced oil recovery. For injection planning, it is extremely important to understand both the initial injection conditions and their changes over time. In the work on the published materials, the world experience of CO2 injection into the reservoir with the aim of its utilization was studied. Using the tools of combined geomechanical modeling of the reservoir, the modeling of the change in the stress-strain state of the massif during the injection process was carried out and the conditions under which the destruction of the reservoir cap and the reactivation of faults occur. The influence of uncertainty in elastic-strength parameters on the critical state of the rock mass and the potential of the permissible injection volume is shown. Comparison of injection potential into reservoirs with terrigenous and carbonate seals has been performed.
{"title":"Geomechanical Modelling Application to Support Reservoir Selection for Carbon Dioxide Utilization and Storage","authors":"E. Korelskiy, Y. Petrakov, Alexey Sobolev, A. Ablaev, D. Mylnikov, D. Melnichuk","doi":"10.2118/206561-ms","DOIUrl":"https://doi.org/10.2118/206561-ms","url":null,"abstract":"\u0000 During recent years reduction of carbon dioxide emission driving development of different technologies for CO2 capturing and utilization. Carbon dioxide injection in underground reservoirs is on of effective methods for storage or utilization as enhanced oil recovery agent. Selection of the potential reservoir for CO2 injection is critically important for long term gas storage. In this paper demonstrated software solutions and workflows for modelling of geomechanical modelling of CO2 injection.\u0000 Injection of CO2 into the reservoir entails a change in reservoir pressure and a change in reservoir temperature. In turn, the stress-strain state of the massif changes, which can lead to the destruction of the reservoir rock and host rocks, reactivation of faults, and, as a consequence, the loss of the integrity of the seal and uncontrolled interstratal crossflows. This paper will describe an example of choosing a reservoir for CO2 injection based on the study of the stress-strain state of the rock mass and its changes due to gas injection.\u0000 Currently, there are various approaches to CO2 recovery into the reservoir, including injection into depleted gas reservoirs, aquifers and oil reservoirs for the purpose of enhanced oil recovery. For injection planning, it is extremely important to understand both the initial injection conditions and their changes over time.\u0000 In the work on the published materials, the world experience of CO2 injection into the reservoir with the aim of its utilization was studied.\u0000 Using the tools of combined geomechanical modeling of the reservoir, the modeling of the change in the stress-strain state of the massif during the injection process was carried out and the conditions under which the destruction of the reservoir cap and the reactivation of faults occur. The influence of uncertainty in elastic-strength parameters on the critical state of the rock mass and the potential of the permissible injection volume is shown. Comparison of injection potential into reservoirs with terrigenous and carbonate seals has been performed.","PeriodicalId":11017,"journal":{"name":"Day 2 Wed, October 13, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82060107","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. Vainshtein, G. Fisher, Gleb Strizhnev, S. Boronin, A. Osiptsov, I. Abdrakhmanov, G. Paderin, A. Prutsakov, R. Uchuev, I. Garagash, K. Tolmacheva, E. Shel, D. Prunov, N. Chebykin, I. Fayzullin
We present the results of field experiments campaign on start-up of wells located in a sandstone oilfield of Western Siberia and history matching of coupled "wellbore-hydraulic fracture" model describing well start-up and fracture clean-up. The conclusion is made about the impact of rheological and geomechanical factors on the well cumulative production andfracture conductivity.The results are generalized for four wells of the field experiment and 30 wells of the retrospective analysis. Calculations of well startup are carried out using standalone fracture cleanup model and the coupled model, which includes models for filtration inside closed hydraulic fracture and flow in the wellbore. The data obtained during field tests on well startup is used to history match the fracture clean-up model. The adaptation allows to evaluate the sensitivity of well production to various physical parameters and find the safe operating envelope of operational parameters during well startup. Numerical simulations allow take into account geomechanics effectsand rheology properties of fracturing fluid, study the dynamics of effective (cleaned) fracture length as well as evaluate the influence of pressure drop dynamics on filtration properties of the fracture and cumulative well production. We extended the number of wells to study the impact of flowback scenarios on production andgeneralized the results of our previous study.Key parameters affecting the history match process of the mathematical model are determined,the uncertainty associated with fluid rheology is reduced. Using the history-matched model, we evaluated geomechanics effects on fracture degradation depending on bottom-hole pressure drop dynamics. Based on the obtained dynamics of dimensionless parameters, such as pressure and fracture productivity, we propose an optimized well start-up strategy aimed at maximizing effective fracture length and cumulative production. Additionally, we visualized the dynamics of fracture conductivity distribution along its length. The obtained results are consistent with interpretation of physical processes accompanying well start-up and fracture clean-up. Dimensionless productivity index is chosen to quantify the effects of geomechanics and fluid rheology on well production.On the basis of matched mathematical model, we predict a potential increase in production of the well with optimized start-up.The recommendations are presented in the form of the dynamics of wellhead choke opening and a sequence of choke diameters. We propose an integrated approach for planning a well flowback strategy after multi-stage hydraulic fracturing. The proposed decision-making algorithm considers the effects of geomechanics and yield-stress hydraulic fracturing fluid rheology on cumulative production. It allows to develop a design for the well start-up and fracture cleanup in terms of dynamics of wellheadchoke opening.
{"title":"Field Testing of the Flowback Technology for Multistage-Fractured Horizontal Wells: Generalization to Find an Optimum Balance Between Aggressive and Smooth Scenarios","authors":"A. Vainshtein, G. Fisher, Gleb Strizhnev, S. Boronin, A. Osiptsov, I. Abdrakhmanov, G. Paderin, A. Prutsakov, R. Uchuev, I. Garagash, K. Tolmacheva, E. Shel, D. Prunov, N. Chebykin, I. Fayzullin","doi":"10.2118/206635-ms","DOIUrl":"https://doi.org/10.2118/206635-ms","url":null,"abstract":"\u0000 We present the results of field experiments campaign on start-up of wells located in a sandstone oilfield of Western Siberia and history matching of coupled \"wellbore-hydraulic fracture\" model describing well start-up and fracture clean-up. The conclusion is made about the impact of rheological and geomechanical factors on the well cumulative production andfracture conductivity.The results are generalized for four wells of the field experiment and 30 wells of the retrospective analysis.\u0000 Calculations of well startup are carried out using standalone fracture cleanup model and the coupled model, which includes models for filtration inside closed hydraulic fracture and flow in the wellbore. The data obtained during field tests on well startup is used to history match the fracture clean-up model. The adaptation allows to evaluate the sensitivity of well production to various physical parameters and find the safe operating envelope of operational parameters during well startup. Numerical simulations allow take into account geomechanics effectsand rheology properties of fracturing fluid, study the dynamics of effective (cleaned) fracture length as well as evaluate the influence of pressure drop dynamics on filtration properties of the fracture and cumulative well production.\u0000 We extended the number of wells to study the impact of flowback scenarios on production andgeneralized the results of our previous study.Key parameters affecting the history match process of the mathematical model are determined,the uncertainty associated with fluid rheology is reduced. Using the history-matched model, we evaluated geomechanics effects on fracture degradation depending on bottom-hole pressure drop dynamics. Based on the obtained dynamics of dimensionless parameters, such as pressure and fracture productivity, we propose an optimized well start-up strategy aimed at maximizing effective fracture length and cumulative production. Additionally, we visualized the dynamics of fracture conductivity distribution along its length. The obtained results are consistent with interpretation of physical processes accompanying well start-up and fracture clean-up. Dimensionless productivity index is chosen to quantify the effects of geomechanics and fluid rheology on well production.On the basis of matched mathematical model, we predict a potential increase in production of the well with optimized start-up.The recommendations are presented in the form of the dynamics of wellhead choke opening and a sequence of choke diameters.\u0000 We propose an integrated approach for planning a well flowback strategy after multi-stage hydraulic fracturing. The proposed decision-making algorithm considers the effects of geomechanics and yield-stress hydraulic fracturing fluid rheology on cumulative production. It allows to develop a design for the well start-up and fracture cleanup in terms of dynamics of wellheadchoke opening.","PeriodicalId":11017,"journal":{"name":"Day 2 Wed, October 13, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87552150","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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