Denis Yurievich Pisarev, Ildar Fanurovich Sharipov, A. Aslanyan, D. Gulyaev, Anastasiya Nikolaevna Nikonorova
The study field is located in the Nizhnevartovsk district of the Khanty-Mansi autonomous region. The deposit is located in the Nizhnevartovsk crest zone. The geological section of this deposit features a thick layer (2740-2870 meters) of Meso-Cenozoic era sedimentary rocks starting from the Jurassic period up to and including the Quaternary period, and rests unconformably on the surface of the deposits of the folded Paleozoic basement. The pay zones of study oil and gas fields features mainly sandstone-siltstone reservoirs. The study formation XX11-2 features interleaved rocks with a high clay content. In the west and south-west of the field, the oil-saturated thicknesses vary on average from 5-10 m, and in the north, the thickness increases to 10-20 m. This field has a long-lasting production history as a result of drilling vertical and horizontal wells but is currently at production decline stage. The existing reservoir pressure support system assumes that the water-cut trend at the wells will increase. In recent years, there has been advanced flooding in some areas, resulting in a drop in oil production, while the reasons for the advanced flooding are not always clear. This is often due to the progressing spontaneous fracturing in the injector wells (Aslanyan, Akimov et al., 2020).
{"title":"Oil Production Enhancement by EOR Candidates Optimization","authors":"Denis Yurievich Pisarev, Ildar Fanurovich Sharipov, A. Aslanyan, D. Gulyaev, Anastasiya Nikolaevna Nikonorova","doi":"10.2118/206498-ms","DOIUrl":"https://doi.org/10.2118/206498-ms","url":null,"abstract":"The study field is located in the Nizhnevartovsk district of the Khanty-Mansi autonomous region. The deposit is located in the Nizhnevartovsk crest zone. The geological section of this deposit features a thick layer (2740-2870 meters) of Meso-Cenozoic era sedimentary rocks starting from the Jurassic period up to and including the Quaternary period, and rests unconformably on the surface of the deposits of the folded Paleozoic basement. The pay zones of study oil and gas fields features mainly sandstone-siltstone reservoirs.\u0000 The study formation XX11-2 features interleaved rocks with a high clay content. In the west and south-west of the field, the oil-saturated thicknesses vary on average from 5-10 m, and in the north, the thickness increases to 10-20 m.\u0000 This field has a long-lasting production history as a result of drilling vertical and horizontal wells but is currently at production decline stage. The existing reservoir pressure support system assumes that the water-cut trend at the wells will increase. In recent years, there has been advanced flooding in some areas, resulting in a drop in oil production, while the reasons for the advanced flooding are not always clear. This is often due to the progressing spontaneous fracturing in the injector wells (Aslanyan, Akimov et al., 2020).","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"63 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75986620","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}
S. Igitov, I.N. Esipenok, A.M. Ishkinov, Anastasiia Sergeevna Vanina, Konstantin Gennadievich Olkhovsky, D. Romanov, Sergey Anatolyevich Lyubimov, Natalia Alexandrovna Goncharova, Valeriya Sergeevna Krikunova
The aim of the article is creation a conceptual model based on the data of chromatic technology data interpretation to improve the quality of forecasting potentially productive areas of occurrence of Jurassic formations of the Tyumen formation, as well as ranking the deposit by priority zones based on multifactor analysis. The article uses methods of complex reinterpretation of seismic and geological-geophysical materials in order to search for and localize highly productive zones of the Tyumen formation formations. The result of the work is a detailed strategy formed: the exploration and production drilling of the J2 formation. A significant increase in the expected ability of potentially productive objects in the inter-well space in the conditions of complex reservoirs due to modern processing technologies and interpretation was noted. The prospects of translating the methodology for optimizing the development of Jurassic objects of the Tyumen Fm at the fields of Slavneft-Megionneftegaz and other assets of Russian oil producing companies are revealed.
{"title":"Application of the Results of Chromatic Technology Data Interpretation in Seismogeological Modeling of Continental Deposits of Western Siberia on the Example of the Zapadno-Ust-Balykskoe Field","authors":"S. Igitov, I.N. Esipenok, A.M. Ishkinov, Anastasiia Sergeevna Vanina, Konstantin Gennadievich Olkhovsky, D. Romanov, Sergey Anatolyevich Lyubimov, Natalia Alexandrovna Goncharova, Valeriya Sergeevna Krikunova","doi":"10.2118/206599-ms","DOIUrl":"https://doi.org/10.2118/206599-ms","url":null,"abstract":"\u0000 The aim of the article is creation a conceptual model based on the data of chromatic technology data interpretation to improve the quality of forecasting potentially productive areas of occurrence of Jurassic formations of the Tyumen formation, as well as ranking the deposit by priority zones based on multifactor analysis. The article uses methods of complex reinterpretation of seismic and geological-geophysical materials in order to search for and localize highly productive zones of the Tyumen formation formations. The result of the work is a detailed strategy formed: the exploration and production drilling of the J2 formation. A significant increase in the expected ability of potentially productive objects in the inter-well space in the conditions of complex reservoirs due to modern processing technologies and interpretation was noted. The prospects of translating the methodology for optimizing the development of Jurassic objects of the Tyumen Fm at the fields of Slavneft-Megionneftegaz and other assets of Russian oil producing companies are revealed.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"44 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74960285","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. Kazakov, R. Gaynetdinov, A. Churakov, Ildar Shamilevich Basyrov, Anna Vladimirovna Galysheva, R. Musin, I. Fayzullin, N. Chebykin, R. Uchuev, I. Vikhman, A. V. Kamenskiy, E. N. Kichigin
The article describes an approach to creating, in conditions of limited input information, a strategy for performing the first hydraulic fracturing operations on deviated and horizontal wells in the A. Zhagrin field. The field is in the active phase of exploration, the planned count is mainly composed of horizontal wells with multi-stage hydraulic fracturing. Approaches to the design of pilot works with control of the height of hydraulic fractures, which have proved their effectiveness by well logging studies and the obtained oil productivity, they have been successfully introduced into the technology of multistage hydraulic fracturing in horizontal wells. Due to the minimum number of reference wells, a significant area of the field (100 km2), the uncertainty of the distribution of water-saturated zones in the target and adjacent formations, the spread in the thickness of clay layers from 10 to 30 m, there is a risk of unwanted introduction of these interlayers by hydraulic fractures. The project team was able to assess the risks in terms of hydraulic fracturing, depending on the geological and physical characteristics (thickness of the target formation and clay layers, saturation) and in joint cross-functional work (with geological, geomechanical and hydrodynamic support) to implement hydraulic fracturing technologies that have confirmed their efficiency in oil production. To test hypotheses at the initial stage, various scenario conditions with a probabilistic assessment of uncertainties were selected at the deviated wells, as a result, the matrix of technological solutions was developed. In directional wells, the capabilities of technologies selected for pilot testing were confirmed using methods for diagnosing the height of hydraulic fracturing. The performed correction of stress profiles in a modern corporate hydraulic fracturing simulator increased the correctness of the 3D geomechanical model, which made it possible to optimize fracture geometry and horizontal wellbore drilling direction. Due to a thorough study of the conditions for the applicability of the considered hydraulic fracturing technologies, it was excluded the inclusion of water-saturated horizons without losing the effective half-length of hydraulic fractures. The workflow, during the implementation of which a matrix of solutions for successful well development was created, will ensure the achievement of planned oil production rates in the future for a field without rich field practice in hydraulic fracturing.
{"title":"Complex Approach to Green Fields Development and Fracturing Strategy by the Example of Pilot on the Field by Name of Alexandra Zhagrina","authors":"E. Kazakov, R. Gaynetdinov, A. Churakov, Ildar Shamilevich Basyrov, Anna Vladimirovna Galysheva, R. Musin, I. Fayzullin, N. Chebykin, R. Uchuev, I. Vikhman, A. V. Kamenskiy, E. N. Kichigin","doi":"10.2118/206649-ms","DOIUrl":"https://doi.org/10.2118/206649-ms","url":null,"abstract":"\u0000 The article describes an approach to creating, in conditions of limited input information, a strategy for performing the first hydraulic fracturing operations on deviated and horizontal wells in the A. Zhagrin field. The field is in the active phase of exploration, the planned count is mainly composed of horizontal wells with multi-stage hydraulic fracturing. Approaches to the design of pilot works with control of the height of hydraulic fractures, which have proved their effectiveness by well logging studies and the obtained oil productivity, they have been successfully introduced into the technology of multistage hydraulic fracturing in horizontal wells. Due to the minimum number of reference wells, a significant area of the field (100 km2), the uncertainty of the distribution of water-saturated zones in the target and adjacent formations, the spread in the thickness of clay layers from 10 to 30 m, there is a risk of unwanted introduction of these interlayers by hydraulic fractures. The project team was able to assess the risks in terms of hydraulic fracturing, depending on the geological and physical characteristics (thickness of the target formation and clay layers, saturation) and in joint cross-functional work (with geological, geomechanical and hydrodynamic support) to implement hydraulic fracturing technologies that have confirmed their efficiency in oil production. To test hypotheses at the initial stage, various scenario conditions with a probabilistic assessment of uncertainties were selected at the deviated wells, as a result, the matrix of technological solutions was developed. In directional wells, the capabilities of technologies selected for pilot testing were confirmed using methods for diagnosing the height of hydraulic fracturing. The performed correction of stress profiles in a modern corporate hydraulic fracturing simulator increased the correctness of the 3D geomechanical model, which made it possible to optimize fracture geometry and horizontal wellbore drilling direction. Due to a thorough study of the conditions for the applicability of the considered hydraulic fracturing technologies, it was excluded the inclusion of water-saturated horizons without losing the effective half-length of hydraulic fractures. The workflow, during the implementation of which a matrix of solutions for successful well development was created, will ensure the achievement of planned oil production rates in the future for a field without rich field practice in hydraulic fracturing.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"33 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81506674","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}
R. Nepop, Nikolay Smirnov, R. Molodtsov, V. Reyes Ahumada, M. Nizametdinova, J.J. Polushina, N. Kudlaeva, T.Y Dolgushin, A. Maltsev, Nikolay Khazov
The geological features of the reservoir structure are of great importance in the development of oil and gas fields in the West Siberian. A productive formation is usually considered as an integral system that includes two interrelated components: rocks and fluid. In this system, the appearance of water is usually associated with negative consequences - a decrease in the elastic-strength properties of geological substrate and the loss of reservoir rocks stability. How critical is the emergence of water from a well construction and / or operation point of view? The search for an answer to this question has become the main goal of the multidisciplinary investigations presented in this paper. In the framework of these studies, an assessment of the in-time stability of an open borehole in case of presence or penetrating different reservoir fluids was carried out. The calculations were based on the high-resolution 4D modeling, which took into consideration the main dynamic and geomechanical effects stipulated by different production scenarios. The concepts of the interrelations in the "rock - fluid" system were based on the results of special core studies. The main idea of these experiments was to reproduce the saturation conditions of reservoirs, initially related to transition zones and characterized by the presence of different types of fluids (formation water / oil). Testing was carried out on duplicate samples, which were characterized by very similar petrophysical properties, and were saturated with various models of formation fluid. The research program included both standard geomechanical tests and experiments on a thick-walled cylinder, as well as experiments with brine of different chemical composition, salinity, temperature and affected by different methods of saturation. Obtained results confirmed the substantial influence of the formation fluid on the elastic-strength properties of the rocks. At the same time, a fundamental role is played not only by the type of saturating fluid, but also by the saturation technique. Several such techniques of core material saturation were analyzed. It provides critical knowledge for calculating the stability of the wellbore in conditions of incompatibility of fluids and rocks, modeling water breakthroughs and sand production, and also for calculating temporal effects. Further modeling made it possible to predict the change in open hole stability under different production scenarios. Finally, it was demonstrated that even with a significant water cut (up to 50%), it is possible to keep the wellbore open and to continue the well operation. The results obtained become critical for evaluating the performance of the field at a later stage of development, especially when there are risks of water breakthrough into the reservoir. The main paradigm in which the industry is currently operating is the idea that the appearance (breakthrough) of formation water leads to a decrease in the strength of the rocks,
{"title":"Fundamental Aspects of Oilfield Development with Water Breakthrough Risks - Time for a Paradigm Change","authors":"R. Nepop, Nikolay Smirnov, R. Molodtsov, V. Reyes Ahumada, M. Nizametdinova, J.J. Polushina, N. Kudlaeva, T.Y Dolgushin, A. Maltsev, Nikolay Khazov","doi":"10.2118/206590-ms","DOIUrl":"https://doi.org/10.2118/206590-ms","url":null,"abstract":"\u0000 The geological features of the reservoir structure are of great importance in the development of oil and gas fields in the West Siberian. A productive formation is usually considered as an integral system that includes two interrelated components: rocks and fluid. In this system, the appearance of water is usually associated with negative consequences - a decrease in the elastic-strength properties of geological substrate and the loss of reservoir rocks stability. How critical is the emergence of water from a well construction and / or operation point of view? The search for an answer to this question has become the main goal of the multidisciplinary investigations presented in this paper.\u0000 In the framework of these studies, an assessment of the in-time stability of an open borehole in case of presence or penetrating different reservoir fluids was carried out. The calculations were based on the high-resolution 4D modeling, which took into consideration the main dynamic and geomechanical effects stipulated by different production scenarios.\u0000 The concepts of the interrelations in the \"rock - fluid\" system were based on the results of special core studies. The main idea of these experiments was to reproduce the saturation conditions of reservoirs, initially related to transition zones and characterized by the presence of different types of fluids (formation water / oil). Testing was carried out on duplicate samples, which were characterized by very similar petrophysical properties, and were saturated with various models of formation fluid.\u0000 The research program included both standard geomechanical tests and experiments on a thick-walled cylinder, as well as experiments with brine of different chemical composition, salinity, temperature and affected by different methods of saturation. Obtained results confirmed the substantial influence of the formation fluid on the elastic-strength properties of the rocks. At the same time, a fundamental role is played not only by the type of saturating fluid, but also by the saturation technique. Several such techniques of core material saturation were analyzed. It provides critical knowledge for calculating the stability of the wellbore in conditions of incompatibility of fluids and rocks, modeling water breakthroughs and sand production, and also for calculating temporal effects. Further modeling made it possible to predict the change in open hole stability under different production scenarios. Finally, it was demonstrated that even with a significant water cut (up to 50%), it is possible to keep the wellbore open and to continue the well operation. The results obtained become critical for evaluating the performance of the field at a later stage of development, especially when there are risks of water breakthrough into the reservoir.\u0000 The main paradigm in which the industry is currently operating is the idea that the appearance (breakthrough) of formation water leads to a decrease in the strength of the rocks, ","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"9 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81668717","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 increasing requirements for reducing the carbon footprint on the part of end users of hydrocarbons, there is a need to develop a system for automated analysis of the main business processes of oil and gas field development to assess greenhouse gas emissions, as well as for optimization in order to improve environmental safety. The paper describes a prototype of a platform that was developed for decarbonization of oil and gas enterprises using modern optimization tools and up-to-date methods for inventory of greenhouse gas emissions. The platform is based on the following models: – simulation model (IM) – simulates the company's business processes, identifying weaknesses and areas of potential development, is a set of mathematical algorithms for solving direct problems; – optimization model (OM) – allows to conduct a comprehensive analysis with a large number of parameters, excluding manual data processing and using automated information exchange between various software that is used in the oil and gas industry for modeling and monitoring of various processes, as well as developing various development options (taking into account geological conditions, geophysical interpretation, etc.). The initial conditions and the specified criteria related to economic indicators allow to solve the problem of finding the optimal parameters for the development of the selected asset. This paper shows the economic effect of implementing software based on a digital twin, implemented as a platform with the ability to build a model of an oil and gas asset, using various data (SAP, 1C, IPM GAP, Repos, Eclipse, etc.) and targets for the development. In the same way, the possible losses of the oil and gas industry from the introduction of additional carbon taxation and the potential for optimizing processes to minimize these costs are considered. IPCC methods are used to calculate greenhouse gas emissions, and direct, indirect, and fugitive emissions are considered in the calculation. The main conclusion is the need to reduce the costs for oil and gas companies and prepare modern automated digital solutions for accounting for greenhouse gas emissions in advance to achieve a zero-carbon footprint and maintain the competitiveness of the Russian oil and gas industry. As a result of the work done, the feasibility was justified, and the result was demonstrated to the customer for calculating greenhouse gas emissions based on digital twins of key business processes of oil and gas enterprises. The use of automated systems makes it possible to reduce the potential economic risks associated with the introduction of a carbon fee from large oil and gas consumers.
{"title":"Digital platform for E&P Assets Business Process Optimization with a Module for Estimation and Optimizing of Greenhouse Gases Emissions. Case Study","authors":"D. Tokarev, Dmitry Tailakov, A. Ablaev","doi":"10.2118/206607-ms","DOIUrl":"https://doi.org/10.2118/206607-ms","url":null,"abstract":"\u0000 Due to the increasing requirements for reducing the carbon footprint on the part of end users of hydrocarbons, there is a need to develop a system for automated analysis of the main business processes of oil and gas field development to assess greenhouse gas emissions, as well as for optimization in order to improve environmental safety. The paper describes a prototype of a platform that was developed for decarbonization of oil and gas enterprises using modern optimization tools and up-to-date methods for inventory of greenhouse gas emissions.\u0000 The platform is based on the following models:\u0000 – simulation model (IM) – simulates the company's business processes, identifying weaknesses and areas of potential development, is a set of mathematical algorithms for solving direct problems; – optimization model (OM) – allows to conduct a comprehensive analysis with a large number of parameters, excluding manual data processing and using automated information exchange between various software that is used in the oil and gas industry for modeling and monitoring of various processes, as well as developing various development options (taking into account geological conditions, geophysical interpretation, etc.). The initial conditions and the specified criteria related to economic indicators allow to solve the problem of finding the optimal parameters for the development of the selected asset.\u0000 This paper shows the economic effect of implementing software based on a digital twin, implemented as a platform with the ability to build a model of an oil and gas asset, using various data (SAP, 1C, IPM GAP, Repos, Eclipse, etc.) and targets for the development. In the same way, the possible losses of the oil and gas industry from the introduction of additional carbon taxation and the potential for optimizing processes to minimize these costs are considered. IPCC methods are used to calculate greenhouse gas emissions, and direct, indirect, and fugitive emissions are considered in the calculation. The main conclusion is the need to reduce the costs for oil and gas companies and prepare modern automated digital solutions for accounting for greenhouse gas emissions in advance to achieve a zero-carbon footprint and maintain the competitiveness of the Russian oil and gas industry.\u0000 As a result of the work done, the feasibility was justified, and the result was demonstrated to the customer for calculating greenhouse gas emissions based on digital twins of key business processes of oil and gas enterprises. The use of automated systems makes it possible to reduce the potential economic risks associated with the introduction of a carbon fee from large oil and gas consumers.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"20 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82731781","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}
Simulators in the petroleum industry have been used mainly for training purposes even though they present different applications like digital twins. In this regard, a simulator must approximate the well environment to reflect operative actions and reactions. This paper describes a case study where a well control simulator has been developed to be used as a digital twin where operators may try different scenarios in a safe environment before applying them to the physical well. To cover all aspects of the operation, the simulator should simulate surface equipment as well as a downhole environment. Numerical modeling techniques and hydraulic simulators are used to design the well response to operations. Different scenarios were established to cover most of the possible downhole problems and equipment malfunctions including electrical and hydraulic failures. The study compares a pre-determined set of KPIs common to three different types of simulation: well control, procedural and an integration of both. The target of the study is to collect the data resulting from the use of the simulator while it replicates a real-life situation. This virtual model of the rig and the well can be used to calibrate the main drilling parameters like SPM, RPM and WOB. The digital twin is also used to optimize operational procedures and improve performance and efficiency of rig crews as well as reduce their response time to possible problems. The results show an increase in performance when the knowledge of the rig is combined with the downhole feedback experience. This proves that training of the crew by reproducing their own equipment allows for a major jump in readiness and faster response with minimal mistakes. In addition, conducting the operation virtually allows the crew to uncover any possible issues before tackling the physical well. This in turn helps to reduce errors and safeguard both well and equipment integrity. This paper discusses the integration of the use of downhole environment behavior into a complete digital twin which will play an important role for providing a source of data for regular case studies concerning well control, Maintenance, Scheduling and other critical decisions. This new method candidates itself as a major contender for the future of simulation in the drilling business and shows the importance of that for reducing risks and errors.
{"title":"A Case Study for the Development and Use of a Well Control Simulator as a Digital Twin of a Real Scenario","authors":"Francesco Curina, Ali Talat Qushchi, Ahmad Aldany","doi":"10.2118/206530-ms","DOIUrl":"https://doi.org/10.2118/206530-ms","url":null,"abstract":"\u0000 Simulators in the petroleum industry have been used mainly for training purposes even though they present different applications like digital twins. In this regard, a simulator must approximate the well environment to reflect operative actions and reactions. This paper describes a case study where a well control simulator has been developed to be used as a digital twin where operators may try different scenarios in a safe environment before applying them to the physical well.\u0000 To cover all aspects of the operation, the simulator should simulate surface equipment as well as a downhole environment. Numerical modeling techniques and hydraulic simulators are used to design the well response to operations. Different scenarios were established to cover most of the possible downhole problems and equipment malfunctions including electrical and hydraulic failures. The study compares a pre-determined set of KPIs common to three different types of simulation: well control, procedural and an integration of both.\u0000 The target of the study is to collect the data resulting from the use of the simulator while it replicates a real-life situation. This virtual model of the rig and the well can be used to calibrate the main drilling parameters like SPM, RPM and WOB. The digital twin is also used to optimize operational procedures and improve performance and efficiency of rig crews as well as reduce their response time to possible problems.\u0000 The results show an increase in performance when the knowledge of the rig is combined with the downhole feedback experience. This proves that training of the crew by reproducing their own equipment allows for a major jump in readiness and faster response with minimal mistakes.\u0000 In addition, conducting the operation virtually allows the crew to uncover any possible issues before tackling the physical well. This in turn helps to reduce errors and safeguard both well and equipment integrity.\u0000 This paper discusses the integration of the use of downhole environment behavior into a complete digital twin which will play an important role for providing a source of data for regular case studies concerning well control, Maintenance, Scheduling and other critical decisions. This new method candidates itself as a major contender for the future of simulation in the drilling business and shows the importance of that for reducing risks and errors.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"219 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"72846852","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 work is devoted to a new direction for geology – interpretation of studied section of sediments through the analysis of microimager data. Imager analysis provides important information about the structural and textural features of rocks, nature of stratification, structural occurrence of the section, natural and technogenic fracturing. The use of borehole microimages in geological and field studies allows us to deepen and expand the existing ideas about the geological structure of known hydrocarbon deposits, and the integrated use of images allows us to solve narrowly focused tasks (Rybalchenko et al., 2016). It is worth to notice that today the potential of reservoir microimagers as a geological GIS tool is underestimated (Isotova et al., 1993) (Mathis et al., 1995) (Donselaar et al., 2005). The most widespread development of borehole imagers abroad occurred in the mid-80s of the XX century. Currently, their use is still gaining popularity in Russia. The use of microimages is not limited to the open trunk of a drilled well, technologies that allow obtaining images directly during drilling are available and widely used (Rybalchenko et al., 2016). From the point of view of well productivity, they can be used to characterize such key parameters as the orientation of horizontal stresses, as well as the intervals of anisotropy, secondary porosity, fracturing and possible crack spread during hydraulic fracturing (Climer et al., 2015). Fine structural and textural features of the section can be used for sedimentological analysis, which means the study of sedimentary rocks in order to establish the processes of their formation - the transport of material, the accumulation of sediments and their diagenetic transformations (Nichols et al., 1999). This analysis is based on the principle of actualism and is carried out using the latest results of studying modern sedimentation processes (Prothero et al., 1996). Imagers are divided into the degree of detail and the scale of measurements:Microimagers – a number of GIS devices, the result of which are images (well scan) with an axial resolution of no more than 1 cm, with a maximum coverage of the wellbore of at least 75% and having a correction for uneven movement and for the intervals of puffs (FMI, FMI-HD, QGEO, QGEO Slim, TBEI of the Wireline division, and also MicroScope HD devices).Imagers – a number of GIS devices, the result of which is images with an axial resolution of no more than 10 cm and/or with a maximum coverage of the wellbore of at least 50%. (FMS, DOBMI, OBMI, UBI divisions of Wireline, and also MicroScope and GeoVISION devices).Macroimagers – a number of GIS devices, the result of which is images (well scan) with an axial resolution of more than 10 cm (geoVISION, EcoScope). Imager - a graphical representation of the walls of the well. It is the result of recording a number of GIS devices. In the diagrams, it is a scan of the cylinder from 0 to 360 degrees, oriented to the cardinal d
通过微成像资料的分析，为研究剖面沉积物的地质解释开辟了新的方向。成像仪分析提供了岩石的构造和结构特征、层理性质、剖面的构造产状、天然和人工压裂的重要信息。在地质和野外研究中使用钻孔微图像使我们能够深化和扩展关于已知油气矿床地质结构的现有想法，并且图像的综合使用使我们能够解决狭窄的重点任务(Rybalchenko等，2016)。值得注意的是，如今储层微成象仪作为地质GIS工具的潜力被低估了(Isotova等人，1993)(Mathis等人，1995)(Donselaar等人，2005)。国外钻孔成像仪最广泛的发展发生在20世纪80年代中期。目前，它们的使用在俄罗斯仍然越来越受欢迎。显微图像的使用并不局限于钻井的主干，在钻井过程中直接获取图像的技术已经得到了广泛的应用(Rybalchenko et al.， 2016)。从油井产能的角度来看，它们可以用来表征水平应力方向、各向异性、次生孔隙度、压裂间隔以及水力压裂过程中可能出现的裂缝扩展等关键参数(Climer等，2015)。该剖面的精细结构和质地特征可用于沉积学分析，即对沉积岩的研究，以确定其形成过程——物质的搬运、沉积物的聚集及其成岩转化(Nichols et al.， 1999)。这种分析是基于现实主义原则，并利用研究现代沉积过程的最新结果进行的(Prothero et al.， 1996)。微成像仪-许多GIS设备，其结果是图像(井扫描)，轴向分辨率不超过1厘米，最大覆盖范围至少为75%，并对不均匀运动和气泡间隔进行校正(FMI, FMI-HD, QGEO, QGEO Slim，有线部门的TBEI，以及显微镜HD设备)。成像仪—许多GIS设备，其结果是轴向分辨率不超过10厘米和/或最大覆盖至少50%的井筒图像。(FMS, DOBMI, OBMI, UBI部门的有线，也显微镜和GeoVISION设备)。大型成像仪-许多GIS设备，其结果是轴向分辨率超过10厘米的图像(井扫描)(geoVISION, EcoScope)。成像仪-井壁的图形表示。它是对多个GIS设备进行记录的结果。在图中，它是一个从0到360度的圆柱体扫描，相对于真北或相对于井的“顶部”(井顶)的基本方向。在本文中，作者展示了微成像仪相对于标准GIS复杂和沉积学岩心研究的信息量的优势，并描述了微成像仪的信息量不低于岩心数据信息量的情况。岩心是研究矿床地质构造链条中最重要的一环。然而，由于地质和技术原因，仅使用岩心很难描述整个地层的特征。同时，成像仪不仅可以作为定性的视觉信息来源，还可以作为定量的视觉信息来源(Brown et al.， 2015)。
{"title":"Lithofacial Interpretation of the Section in the Core Absence Intervals Using Microimager Data","authors":"G. Kazantsev, A. Ivanov","doi":"10.2118/206593-ms","DOIUrl":"https://doi.org/10.2118/206593-ms","url":null,"abstract":"\u0000 This work is devoted to a new direction for geology – interpretation of studied section of sediments through the analysis of microimager data.\u0000 Imager analysis provides important information about the structural and textural features of rocks, nature of stratification, structural occurrence of the section, natural and technogenic fracturing. The use of borehole microimages in geological and field studies allows us to deepen and expand the existing ideas about the geological structure of known hydrocarbon deposits, and the integrated use of images allows us to solve narrowly focused tasks (Rybalchenko et al., 2016). It is worth to notice that today the potential of reservoir microimagers as a geological GIS tool is underestimated (Isotova et al., 1993) (Mathis et al., 1995) (Donselaar et al., 2005). The most widespread development of borehole imagers abroad occurred in the mid-80s of the XX century. Currently, their use is still gaining popularity in Russia. The use of microimages is not limited to the open trunk of a drilled well, technologies that allow obtaining images directly during drilling are available and widely used (Rybalchenko et al., 2016). From the point of view of well productivity, they can be used to characterize such key parameters as the orientation of horizontal stresses, as well as the intervals of anisotropy, secondary porosity, fracturing and possible crack spread during hydraulic fracturing (Climer et al., 2015). Fine structural and textural features of the section can be used for sedimentological analysis, which means the study of sedimentary rocks in order to establish the processes of their formation - the transport of material, the accumulation of sediments and their diagenetic transformations (Nichols et al., 1999). This analysis is based on the principle of actualism and is carried out using the latest results of studying modern sedimentation processes (Prothero et al., 1996).\u0000 Imagers are divided into the degree of detail and the scale of measurements:Microimagers – a number of GIS devices, the result of which are images (well scan) with an axial resolution of no more than 1 cm, with a maximum coverage of the wellbore of at least 75% and having a correction for uneven movement and for the intervals of puffs (FMI, FMI-HD, QGEO, QGEO Slim, TBEI of the Wireline division, and also MicroScope HD devices).Imagers – a number of GIS devices, the result of which is images with an axial resolution of no more than 10 cm and/or with a maximum coverage of the wellbore of at least 50%. (FMS, DOBMI, OBMI, UBI divisions of Wireline, and also MicroScope and GeoVISION devices).Macroimagers – a number of GIS devices, the result of which is images (well scan) with an axial resolution of more than 10 cm (geoVISION, EcoScope).\u0000 Imager - a graphical representation of the walls of the well. It is the result of recording a number of GIS devices. In the diagrams, it is a scan of the cylinder from 0 to 360 degrees, oriented to the cardinal d","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"29 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77398956","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}
Seismic surveys in the vast territory of Eastern Siberia are carried out in seismic and geological conditions of varying complexity. Obtaining a high-quality dynamic seismic image for the work area is a priority task in the states of contrasting heterogeneities of the near-surface. For this, it is necessary to restore an effective depth-velocity model that provides compensation for velocity anomalies and calculates static corrections. However, for the most complex near-surface structure, for example, the presence of trap intrusions and tuffaceous formations, the information content of the velocity models of the near-surface area obtained based on tomographic refinement turns out to be insufficient, and a search for another solution is required. The paper considers an approach based on Full Waveform Inversion (FWI). As the authors showed earlier, multiples associated with the free surface reduce the resolution of this approach. But their use increases the stability of the solution in the presence of uncorrelated noise. Therefore, at the first stage of FWI, the full wavefield is used, including free surface-related multiples, but they are suppressed in the next steps of the data processing. The results obtained demonstrate the ability of the FWI to restore complex geological structures of the near-surface area, even in the presence of high-velocity anomalies (trap intrusions).
{"title":"Reconstruction of the Near-Surface Velocities with Trap Bodies by the Full Waveform Inversion","authors":"K. Gadylshin, V. Cheverda, D. Tverdokhlebov","doi":"10.2118/206594-ms","DOIUrl":"https://doi.org/10.2118/206594-ms","url":null,"abstract":"\u0000 Seismic surveys in the vast territory of Eastern Siberia are carried out in seismic and geological conditions of varying complexity. Obtaining a high-quality dynamic seismic image for the work area is a priority task in the states of contrasting heterogeneities of the near-surface. For this, it is necessary to restore an effective depth-velocity model that provides compensation for velocity anomalies and calculates static corrections. However, for the most complex near-surface structure, for example, the presence of trap intrusions and tuffaceous formations, the information content of the velocity models of the near-surface area obtained based on tomographic refinement turns out to be insufficient, and a search for another solution is required. The paper considers an approach based on Full Waveform Inversion (FWI). As the authors showed earlier, multiples associated with the free surface reduce the resolution of this approach. But their use increases the stability of the solution in the presence of uncorrelated noise. Therefore, at the first stage of FWI, the full wavefield is used, including free surface-related multiples, but they are suppressed in the next steps of the data processing. The results obtained demonstrate the ability of the FWI to restore complex geological structures of the near-surface area, even in the presence of high-velocity anomalies (trap intrusions).","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74450998","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}
R. Karpov, Denis Yurjevich Zubkov, Aleksandr Vitalyevich Murlaev, K. Valiullin
The paper presents a solution to the problem of qualitative determination of actual downhole loads and drilling parameters optimization performed employing a dynamic digital well model. The problem of the surface and downhole sensors data quality is disclosed, a solution for an aggregated data QAQC and achieved results are presented. The implementation of the digital platform and the functionality of the dynamic digital twin allowed us to improve the compliance with desired regimes, enabled ensuring the safety of technological operations, allowed us to speed up decision-making while drilling and well completion and commissioning into production. The digital ecosystem allows to timely respond and control operational parameters, to improve and accurately control ROP while minimizing drilling hazards risks and premature drill bit bits wear. The incorporated dynamic digital twin in real-time allows assuring data quality, analyzing activities efficiency, and defining the optimal drilling parameters. The selection of optimal drilling parameters and an increase in ROP are carried out in real-time, based on the analysis of specific mechanical energy. Quality control of sensors plays a key role in the process of evaluating effective weight to bit and associated loads, and in identifying the current friction factor values exhibited downhole. Further on performed trend analysis of the friction factors and respective changes in key drilling parameters allows to track and prevent critical overloads of the drill string, permits to determine the risks of downhole hazards, enables evaluation of well circulation and conditioning activities efficiency in a given interval – allows reducing invisible NPT and the risks of downhole complications. The introduction of a digital ecosystem and a dynamic digital twin allowed us to bring the well construction management process to the next level. Operational response and the decision-making process has been drastically accelerated and improved. Uncertainties associated with an expert's interpretation of drilling states, and subjectivity in the opinions on the effectiveness of processes were eliminated. The negative effect of the human factor and the resulting invisible nonproductive time was minimized. In a short period, the drilling contractor was able to integrate a single digital platform, improve key performance indicators, and involve the field personnel in the full cycle of the technological process of well construction. Field and office personnel, including the driller, can work in a single digital platform, and regardless of the current operation, do always know the true downhole loads, do see the allowable operating envelope and optimal values of the hook load, surface torque, SPP, flow rate, RPM, weight, and torque on the bit, ROP and tripping speeds. The presented method of assessing the quality of the readings of measuring devices and determining the true WOB allows us to optimize the technological paramete
{"title":"Drilling Performance and Data Quality Control with Live Digital Twin","authors":"R. Karpov, Denis Yurjevich Zubkov, Aleksandr Vitalyevich Murlaev, K. Valiullin","doi":"10.2118/206527-ms","DOIUrl":"https://doi.org/10.2118/206527-ms","url":null,"abstract":"\u0000 The paper presents a solution to the problem of qualitative determination of actual downhole loads and drilling parameters optimization performed employing a dynamic digital well model. The problem of the surface and downhole sensors data quality is disclosed, a solution for an aggregated data QAQC and achieved results are presented. The implementation of the digital platform and the functionality of the dynamic digital twin allowed us to improve the compliance with desired regimes, enabled ensuring the safety of technological operations, allowed us to speed up decision-making while drilling and well completion and commissioning into production. The digital ecosystem allows to timely respond and control operational parameters, to improve and accurately control ROP while minimizing drilling hazards risks and premature drill bit bits wear.\u0000 The incorporated dynamic digital twin in real-time allows assuring data quality, analyzing activities efficiency, and defining the optimal drilling parameters. The selection of optimal drilling parameters and an increase in ROP are carried out in real-time, based on the analysis of specific mechanical energy. Quality control of sensors plays a key role in the process of evaluating effective weight to bit and associated loads, and in identifying the current friction factor values exhibited downhole. Further on performed trend analysis of the friction factors and respective changes in key drilling parameters allows to track and prevent critical overloads of the drill string, permits to determine the risks of downhole hazards, enables evaluation of well circulation and conditioning activities efficiency in a given interval – allows reducing invisible NPT and the risks of downhole complications.\u0000 The introduction of a digital ecosystem and a dynamic digital twin allowed us to bring the well construction management process to the next level. Operational response and the decision-making process has been drastically accelerated and improved. Uncertainties associated with an expert's interpretation of drilling states, and subjectivity in the opinions on the effectiveness of processes were eliminated. The negative effect of the human factor and the resulting invisible nonproductive time was minimized. In a short period, the drilling contractor was able to integrate a single digital platform, improve key performance indicators, and involve the field personnel in the full cycle of the technological process of well construction. Field and office personnel, including the driller, can work in a single digital platform, and regardless of the current operation, do always know the true downhole loads, do see the allowable operating envelope and optimal values of the hook load, surface torque, SPP, flow rate, RPM, weight, and torque on the bit, ROP and tripping speeds.\u0000 The presented method of assessing the quality of the readings of measuring devices and determining the true WOB allows us to optimize the technological paramete","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"111 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79190011","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. Chaplygin, D. Khamadaliev, A. Sednev, Dmitry Naimushin
One of the main objectives for the successful development of the majority of producing oil and gas companies in western Siberia is the development of the Achimov strata. It contains a commercially attractive volume of reserves. This reservoir in most oilfields belongs to the hard-to-recover oil - it has a permeability of less than 2 mD. In this regard, the development of the Achimov strata is impossible without carrying out measures for production enhancement. Where most common is hydraulic fracturing. The wells tests with hydraulic fracturing conducted at the Salym group of fields showed that not all reserves are economically attractive, and the decline rate in the first year is extremely high. In this connection, the needs of finding more effective solutions for the production enhancement has become urgent. This article describes the results of pilot work on two wells using a mixture based on a high-viscosity friction reducer (HVFR) as the hydraulic fracturing fluid. The work was carried out at wells where hydraulic fracturing based on cross-linked gel had already been performed and the wells were launched into production. The results of the work, the lessons learned and the analysis of the subsequent production of these wells is the purpose of this work.
{"title":"Case Studies of Re-Fracturing Achimov Reservoirs with High-Viscous Friction Reducer on Salym Group of Oilfields","authors":"D. Chaplygin, D. Khamadaliev, A. Sednev, Dmitry Naimushin","doi":"10.2118/206650-ms","DOIUrl":"https://doi.org/10.2118/206650-ms","url":null,"abstract":"\u0000 One of the main objectives for the successful development of the majority of producing oil and gas companies in western Siberia is the development of the Achimov strata. It contains a commercially attractive volume of reserves. This reservoir in most oilfields belongs to the hard-to-recover oil - it has a permeability of less than 2 mD. In this regard, the development of the Achimov strata is impossible without carrying out measures for production enhancement. Where most common is hydraulic fracturing.\u0000 The wells tests with hydraulic fracturing conducted at the Salym group of fields showed that not all reserves are economically attractive, and the decline rate in the first year is extremely high. In this connection, the needs of finding more effective solutions for the production enhancement has become urgent.\u0000 This article describes the results of pilot work on two wells using a mixture based on a high-viscosity friction reducer (HVFR) as the hydraulic fracturing fluid. The work was carried out at wells where hydraulic fracturing based on cross-linked gel had already been performed and the wells were launched into production.\u0000 The results of the work, the lessons learned and the analysis of the subsequent production of these wells is the purpose of this work.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"19 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83096392","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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