M. V. Zvada, Pavel Nikolaevich Belovus, Evgeny Ivanovich Sergeev, N. Glavnov, M. Varfolomeev, E. Saifullin
This article describes the assessment of effectiveness of gel and foaming agents for gas shut-off treatments in horizontal wells. The research is carried out through the implementation of a complex of special laboratory studies and analysis of the results using numerical modeling methods. A list of necessary laboratory experiments to minimize risks when carrying out work to limit gas inflow has been formulated, and approaches to carrying it out have been described. The program includes: free volume studies, filtration on linear and parallel core models. The results confirm the importance of studying not only the agent's physical characteristics at the reservoir conditions, but their interaction with reservoir fluids. The influence of different agents on the mobility of gas and oil was assessed as a result of linear core flooding experiments. In addition, the filtration tests on parallel cores were carried out aimed to determining the saturation selectivity. The series of numerical calculations was performed for the subsequent determination of the technological and economic effects of the treatment with gas blockers.
{"title":"Study of the Efficiency of Gel and Polymer-Stabilized Foam Systems for Gas Shut-Off in Horizontal Wells","authors":"M. V. Zvada, Pavel Nikolaevich Belovus, Evgeny Ivanovich Sergeev, N. Glavnov, M. Varfolomeev, E. Saifullin","doi":"10.2118/206404-ms","DOIUrl":"https://doi.org/10.2118/206404-ms","url":null,"abstract":"\u0000 This article describes the assessment of effectiveness of gel and foaming agents for gas shut-off treatments in horizontal wells. The research is carried out through the implementation of a complex of special laboratory studies and analysis of the results using numerical modeling methods.\u0000 A list of necessary laboratory experiments to minimize risks when carrying out work to limit gas inflow has been formulated, and approaches to carrying it out have been described. The program includes: free volume studies, filtration on linear and parallel core models. The results confirm the importance of studying not only the agent's physical characteristics at the reservoir conditions, but their interaction with reservoir fluids.\u0000 The influence of different agents on the mobility of gas and oil was assessed as a result of linear core flooding experiments. In addition, the filtration tests on parallel cores were carried out aimed to determining the saturation selectivity.\u0000 The series of numerical calculations was performed for the subsequent determination of the technological and economic effects of the treatment with gas blockers.","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":"76878216","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. Anikeev, E. Zakirov, I. Indrupskiy, E. S. Anikeeva
This article discusses the problem of creating a gas storage facility for mixed hydrogen with methane (underground hydrogen storage - UHS) in an aquifer. At the same time, hydrogen is the most expensive valuable substance in the mixture. It is assumed that the hydrogen injection process and its storage life cycle should ensure the most complete re-production of the injected hydrogen even after several years. The distinctive features of injected gas mixture propagation within an aquifer are considered in this paper, taking into account a number of phenomena. For example, the effects of degassing though the caprocks and migration due to natural water flows from aquifers associated with the target formation. In our previous article SPE 201999 (Abukova et al., 2020) we proposed an efficient storage and subsequent production system that allows to control the geometry and volume of a gas bubble in an aquifer. At the same time, our article (Abukova et al., 2020) considered only flow processes occurring throughout the entire life cycle of the storage facility. Previously, diffusion losses of hydrogen especially through the caprocks were estimated by a number of researchers as being significant. According to the results of large-scale simulation presented in the current article, those losses are estimated as being negligible. The results of this paper were obtained on the basis of large-scale 3D geological and flow modeling of a multicomponent system in the form of a mixture of hydrogen, methane and water in a porous medium for synthetic 3D models. A compositional approach was applied to describe fluid state. The studies were carried out on a certified flow simulator with an additional option of gas diffusion. On a 3D reservoir model the losses of hydrogen through the caprocks under conditions of its low permeability were estimated. Similar losses due to multicomponent diffusion were also evaluated. Upper bounds for diffusion losses were obtained straightforwardly. Corresponding study was carried out for the model from paper (Abukova et al., 2020) with maximum spreading of the injected gas over the top of the reservoir. Estimating calculations showed that if the caprocks remains sealing even with its non-zero permeability, the losses of hydrogen through the caprocks were insignificant. Much greater hydrogen reserves spreading were facilitated by its rapid movement along the top of the reservoir. That is why there is a need for a previously substantiated system of various wells on UHS, which support and control the shape of the storage facility. This article confirms that by creating a pressure barrier controlled due to the concomitant injection of water, it is possible to effectively store hydrogen together with methane in an aquifer. The amount of diffusion losses of hydrogen, as well as its losses through the caprocks, even under the condition of its low permeability, were insignificant. In this regard, the efficiency of creating UHS practically d
本文讨论了在含水层中建立混合氢-甲烷储气设施(地下储氢库- UHS)的问题。同时，氢是混合物中最昂贵的有价值的物质。假设注氢工艺及其储存寿命周期应确保即使在几年后也能最完整地再现所注入的氢气。本文考虑了注入气体在含水层内传播的独特特征，并考虑了一些现象。例如，盖层脱气的影响，以及与目标地层相关的含水层天然水的运移。在我们之前的文章SPE 201999 (Abukova et al.， 2020)中，我们提出了一种高效的储存和后续生产系统，可以控制含水层中气泡的几何形状和体积。同时，我们的文章(Abukova et al.， 2020)只考虑了在存储设施的整个生命周期中发生的流过程。以前，许多研究人员估计氢的扩散损失，特别是通过盖层的扩散损失是显著的。根据本文给出的大规模模拟结果，估计这些损失可以忽略不计。本文的研究结果是在对多孔介质中以氢、甲烷和水混合形式存在的多组分系统进行大规模三维地质和流动建模的基础上得出的。采用组合方法描述流体状态。这些研究是在一个经过认证的流动模拟器上进行的，该模拟器带有额外的气体扩散选项。在三维储层模型上，估计了低渗透条件下通过盖层的氢损失。对多组分扩散造成的类似损失也进行了评估。直接得到了扩散损失的上界。对论文(Abukova et al.， 2020)中的模型进行了相应的研究，其中注入气体在储层顶部的最大扩散。估计计算表明，即使渗透率不为零，如果盖层仍保持密封，则通过盖层的氢损失微不足道。沿着储层顶部的快速移动促进了更大的氢储量的扩散。这就是为什么需要在UHS上建立一个由各种井组成的系统，以支持和控制存储设施的形状。这篇文章证实，通过创造一个压力屏障来控制伴随注入的水，可以有效地将氢气和甲烷一起储存在含水层中。即使在渗透率较低的情况下，氢气的扩散损失量以及通过盖层的损失量也不显著。在这方面，创建UHS的效率实际上与创建传统地下天然气储存设施的效率没有什么不同。
{"title":"Estimation of Diffusion Losses of Hydrogen During the Creation of its Effective Storage in an Aquifer","authors":"D. Anikeev, E. Zakirov, I. Indrupskiy, E. S. Anikeeva","doi":"10.2118/206614-ms","DOIUrl":"https://doi.org/10.2118/206614-ms","url":null,"abstract":"\u0000 This article discusses the problem of creating a gas storage facility for mixed hydrogen with methane (underground hydrogen storage - UHS) in an aquifer. At the same time, hydrogen is the most expensive valuable substance in the mixture. It is assumed that the hydrogen injection process and its storage life cycle should ensure the most complete re-production of the injected hydrogen even after several years. The distinctive features of injected gas mixture propagation within an aquifer are considered in this paper, taking into account a number of phenomena. For example, the effects of degassing though the caprocks and migration due to natural water flows from aquifers associated with the target formation.\u0000 In our previous article SPE 201999 (Abukova et al., 2020) we proposed an efficient storage and subsequent production system that allows to control the geometry and volume of a gas bubble in an aquifer. At the same time, our article (Abukova et al., 2020) considered only flow processes occurring throughout the entire life cycle of the storage facility. Previously, diffusion losses of hydrogen especially through the caprocks were estimated by a number of researchers as being significant. According to the results of large-scale simulation presented in the current article, those losses are estimated as being negligible.\u0000 The results of this paper were obtained on the basis of large-scale 3D geological and flow modeling of a multicomponent system in the form of a mixture of hydrogen, methane and water in a porous medium for synthetic 3D models. A compositional approach was applied to describe fluid state. The studies were carried out on a certified flow simulator with an additional option of gas diffusion.\u0000 On a 3D reservoir model the losses of hydrogen through the caprocks under conditions of its low permeability were estimated. Similar losses due to multicomponent diffusion were also evaluated. Upper bounds for diffusion losses were obtained straightforwardly. Corresponding study was carried out for the model from paper (Abukova et al., 2020) with maximum spreading of the injected gas over the top of the reservoir. Estimating calculations showed that if the caprocks remains sealing even with its non-zero permeability, the losses of hydrogen through the caprocks were insignificant. Much greater hydrogen reserves spreading were facilitated by its rapid movement along the top of the reservoir. That is why there is a need for a previously substantiated system of various wells on UHS, which support and control the shape of the storage facility.\u0000 This article confirms that by creating a pressure barrier controlled due to the concomitant injection of water, it is possible to effectively store hydrogen together with methane in an aquifer. The amount of diffusion losses of hydrogen, as well as its losses through the caprocks, even under the condition of its low permeability, were insignificant. In this regard, the efficiency of creating UHS practically d","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":"89048891","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}
Ruslan Gataullin, S. Ter-Saakov, E. V. Nikulin, Dmitriy Pavlovich Stifeev, A. V. Filatov
This article describes engineering and technology solutions developed to successfully construct unconventional and unique horizontal well at the field of Eastern Siberia targeted to two isolated formations with an option to shut-off top Botuobinsky horizon after gas breakthrough and produce oil from underlying Ulakhansky bed further on. As oil-water contact in the lower part of Ulakhansky horizon makes fracturing the well inexpedient, multi hole drilling technology was implemented enabling drainage of the reserves that are far from the main borehole. The main objective of this well is to deplete Botuobinsky horizon subsequently shutting it off and continuing to recover petroleum reserves from Ulakhansky pay zone. Constructing such well is cost-effective, as it requires drilling only one intermediate casing interval instead of two. Accumulated experience of drilling and completing multi hole wells was used to ensure successful well construction; also, geological and stratigraphic data as well as possible complications while drilling Botuobunsky and Ulakhansky formations were analyzed in-depth. The following appliances were selected to meet the objective: –Bottom-hole equipment enabling drilling abrasive formations under conditions of high vibrations;–Special line of drill bits to ensure high ROP and successful sidetracking without additional tripping;–RSS with 152.4 mm drill bit. The goal set by the operating company was achieved through multi-faceted approach to performing the task, efficient cooperation of engineering technical services and continuous monitoring of output data while drilling. All that combined delivered the results listed below: –Sidetracks were carried out in an open horizontal hole without cement plugs and additional tripping for drill bit or BHA.–Minimized bottom-hole equipment failures under condition of increased high-frequency vibrations from bit while drilling hard formations due to implementation of modular PDM with data-transmitting channel.–Minimized bottom-hole equipment failures under condition of increased low-frequency vibrations from drill string with Hard Bending due to improved BHA design and optimized drilling parameters selection.–Liner was effectively run to Botuobinsky and Ulakhansky reservoirs with an option to shut-off the former after depletion and gas breakthrough. This well is the first one targeted at two isolated formations in East Siberia.
{"title":"The First Multilateral Well in Eastern Siberia on the Separated Oil Reservoirs","authors":"Ruslan Gataullin, S. Ter-Saakov, E. V. Nikulin, Dmitriy Pavlovich Stifeev, A. V. Filatov","doi":"10.2118/206455-ms","DOIUrl":"https://doi.org/10.2118/206455-ms","url":null,"abstract":"\u0000 This article describes engineering and technology solutions developed to successfully construct unconventional and unique horizontal well at the field of Eastern Siberia targeted to two isolated formations with an option to shut-off top Botuobinsky horizon after gas breakthrough and produce oil from underlying Ulakhansky bed further on. As oil-water contact in the lower part of Ulakhansky horizon makes fracturing the well inexpedient, multi hole drilling technology was implemented enabling drainage of the reserves that are far from the main borehole.\u0000 The main objective of this well is to deplete Botuobinsky horizon subsequently shutting it off and continuing to recover petroleum reserves from Ulakhansky pay zone. Constructing such well is cost-effective, as it requires drilling only one intermediate casing interval instead of two.\u0000 Accumulated experience of drilling and completing multi hole wells was used to ensure successful well construction; also, geological and stratigraphic data as well as possible complications while drilling Botuobunsky and Ulakhansky formations were analyzed in-depth.\u0000 The following appliances were selected to meet the objective: –Bottom-hole equipment enabling drilling abrasive formations under conditions of high vibrations;–Special line of drill bits to ensure high ROP and successful sidetracking without additional tripping;–RSS with 152.4 mm drill bit.\u0000 The goal set by the operating company was achieved through multi-faceted approach to performing the task, efficient cooperation of engineering technical services and continuous monitoring of output data while drilling. All that combined delivered the results listed below: –Sidetracks were carried out in an open horizontal hole without cement plugs and additional tripping for drill bit or BHA.–Minimized bottom-hole equipment failures under condition of increased high-frequency vibrations from bit while drilling hard formations due to implementation of modular PDM with data-transmitting channel.–Minimized bottom-hole equipment failures under condition of increased low-frequency vibrations from drill string with Hard Bending due to improved BHA design and optimized drilling parameters selection.–Liner was effectively run to Botuobinsky and Ulakhansky reservoirs with an option to shut-off the former after depletion and gas breakthrough.\u0000 This well is the first one targeted at two isolated formations in East Siberia.","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":"89967402","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}
V. N. Kozhin, A. Mikhailov, Konstantin Vasilievich Pchela, Ivan Ivanovich Kireev, Sergey V. Demin, Pavel Valerevich Roschin, Aleksandr Valerevich Nikitin
The paper presents the results of lab and filtration studies aimed at improving the procedure of thermal/gas/chemical effect (TGCE) with the generation of thermogenic system in reservoir conditions, proposed as an alternative to the methods of increasing oil recovery, such as water-gas effect procedure and foam injection process. The objects of research were thermal/gas generating compositions at the basis of sodium salts of sulfamic and nitric acids. Moreover, the influence of the ionic composition of the aqueous solution and temperature on the surface properties of the attracted solutions of surfactants (surfactants) was also evaluated. Filtration tests have shown that the use of a thermal/gas generating composition leads to additional displacement of high-viscous oil. The introduction of surfactants in the thermal/gas generating composition promotes foaming in the porous medium of the reservoir model and prevents gas breakthrough that leads to an increase in the oil displacement factor up to 24 %.
{"title":"Design Researches in Making In-Situ Thermal Foam System as a New Enhanced Heavy Oil Recovery Method","authors":"V. N. Kozhin, A. Mikhailov, Konstantin Vasilievich Pchela, Ivan Ivanovich Kireev, Sergey V. Demin, Pavel Valerevich Roschin, Aleksandr Valerevich Nikitin","doi":"10.2118/206423-ms","DOIUrl":"https://doi.org/10.2118/206423-ms","url":null,"abstract":"\u0000 The paper presents the results of lab and filtration studies aimed at improving the procedure of thermal/gas/chemical effect (TGCE) with the generation of thermogenic system in reservoir conditions, proposed as an alternative to the methods of increasing oil recovery, such as water-gas effect procedure and foam injection process. The objects of research were thermal/gas generating compositions at the basis of sodium salts of sulfamic and nitric acids. Moreover, the influence of the ionic composition of the aqueous solution and temperature on the surface properties of the attracted solutions of surfactants (surfactants) was also evaluated.\u0000 Filtration tests have shown that the use of a thermal/gas generating composition leads to additional displacement of high-viscous oil. The introduction of surfactants in the thermal/gas generating composition promotes foaming in the porous medium of the reservoir model and prevents gas breakthrough that leads to an increase in the oil displacement factor up to 24 %.","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":"87260788","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. Churakov, M. Pichugin, R. Gaynetdinov, I. G. Faizullin, A. P. Stabinskas, N. Chebykin, R. Uchuev, A. Prutsakov, I. Vikhman, Oleg Viktorovich Syrtlanov, Albert Mukhametov, Ekaterina Valerievna Rusinova, Mikhail Yurievich Shirev, Danil Aleksandrovich Gorelov
In the context of a comprehensive search for ways to optimize and reduce operating costs for hydraulic fracturing operations, one of the areas to consider is the use of alternative water sources for making-up hydraulic fracturing fluids such as Cenomanian, mixed or produced water. This solution allows to optimize the speed and quality of work without wasting time and financial resources due to no need for heating and remote transportation. The main goal of the study was to create a stable guar-based hydraulic fracturing fluid system with a borate crosslinker, which allows high-quality treatment using high-salinity water. Much attention is paid to the composition of real saline sources, i.e. produced, mixed and Cenomanian water, which were sampled from the Gazpromneft-Khantos fields. Based on the data ranking by composition, the main groups of mineral components, as well as the cut-off criteria that determine the behavior of a hydraulic fracturing fluid in linear and cross-linked forms, were identified. The main stage of working on the fluid system quality included two areas: screening stabilizing components that meet the criteria for performing hydraulic fracturing operations, and assessing the fluid clogging properties based on flow tests. To study and select the composition of a hydraulic fracturing fluid, both standard and extended rheological tests were performed, which included core tests on real samples from target reservoirs and tests of residual conductivity and permeability of a proppant pack. The sand-transport properties of the fluid were measured both in static and dynamic conditions. The study resulted in the development of a fluid system complex including stabilizing additives and criteria for their applicability at real field conditions, taking into account the features of the existing equipment of hydraulic fracturing fleets. Experiments have shown that standard guar fluids based on water from alternative sources, when using a complex of stabilizing components, successfully replace the basic set of additives for fresh water, and are quite competitive not only in rheological properties and the ability to transport proppants, but also in restoring the permeability of a proppant pack and core samples. Each stabilizing component of such fluid makes its own unique contribution to achieving the required parameters of the fluid without losing its quality. An important achievement is the development of methods and criteria for the applicability of stabilizing components that make it possible to work with any source, whether it is produced, mixed, or Cenomanian water. The solution allows in a short time to adjust the fluid system depending on the actual mineral composition in a stationary field laboratory without the involvement of specialized equipment and expensive research.
{"title":"Hydraulic Fracturing on Water from Alternative Sources: An Integrated Approach, Ways, and Solutions","authors":"A. Churakov, M. Pichugin, R. Gaynetdinov, I. G. Faizullin, A. P. Stabinskas, N. Chebykin, R. Uchuev, A. Prutsakov, I. Vikhman, Oleg Viktorovich Syrtlanov, Albert Mukhametov, Ekaterina Valerievna Rusinova, Mikhail Yurievich Shirev, Danil Aleksandrovich Gorelov","doi":"10.2118/206634-ms","DOIUrl":"https://doi.org/10.2118/206634-ms","url":null,"abstract":"\u0000 In the context of a comprehensive search for ways to optimize and reduce operating costs for hydraulic fracturing operations, one of the areas to consider is the use of alternative water sources for making-up hydraulic fracturing fluids such as Cenomanian, mixed or produced water. This solution allows to optimize the speed and quality of work without wasting time and financial resources due to no need for heating and remote transportation.\u0000 The main goal of the study was to create a stable guar-based hydraulic fracturing fluid system with a borate crosslinker, which allows high-quality treatment using high-salinity water.\u0000 Much attention is paid to the composition of real saline sources, i.e. produced, mixed and Cenomanian water, which were sampled from the Gazpromneft-Khantos fields. Based on the data ranking by composition, the main groups of mineral components, as well as the cut-off criteria that determine the behavior of a hydraulic fracturing fluid in linear and cross-linked forms, were identified. The main stage of working on the fluid system quality included two areas: screening stabilizing components that meet the criteria for performing hydraulic fracturing operations, and assessing the fluid clogging properties based on flow tests.\u0000 To study and select the composition of a hydraulic fracturing fluid, both standard and extended rheological tests were performed, which included core tests on real samples from target reservoirs and tests of residual conductivity and permeability of a proppant pack. The sand-transport properties of the fluid were measured both in static and dynamic conditions.\u0000 The study resulted in the development of a fluid system complex including stabilizing additives and criteria for their applicability at real field conditions, taking into account the features of the existing equipment of hydraulic fracturing fleets. Experiments have shown that standard guar fluids based on water from alternative sources, when using a complex of stabilizing components, successfully replace the basic set of additives for fresh water, and are quite competitive not only in rheological properties and the ability to transport proppants, but also in restoring the permeability of a proppant pack and core samples. Each stabilizing component of such fluid makes its own unique contribution to achieving the required parameters of the fluid without losing its quality.\u0000 An important achievement is the development of methods and criteria for the applicability of stabilizing components that make it possible to work with any source, whether it is produced, mixed, or Cenomanian water. The solution allows in a short time to adjust the fluid system depending on the actual mineral composition in a stationary field laboratory without the involvement of specialized equipment and expensive research.","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":"85765104","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}
T. E. Nigmatullin, Vladislav Yurievich Nikulin, A. R. Shaymardanov, R. R. Mukminov, Alexandr Yurievich Ivanov, Marat Edgarovich Akhmadullin, Dzheykhun Soltanov
The article describes the choosing a water-and-gas shutoff technology in horizontal wells (HW) drilled in terrigenous reservoirs of the North Komsomolskoye field. The well completion system is characterized by the use of liners equipped with external liner packers and inflow control devices (ICD). To solve the problem, the world experience in the use the water-and-gas shutoff technologies in HW was studied. A matrix for choosing a technology with the use of technical means and combined effect was developed based on the type of isolated fluid, the type of reservoir and the method of well completion. The technology of installing a straddle system with cup packers and a blind inter-packer pipe in a horizontal wellbore was selected to increase the success of work on isolating the inflow of water and gas in difficult geological conditions of the North Komsomolskoye field. The technology was successfully tested: a producing well with almost 100% water cut was return to effective production. A similar straddle system, but with a perforated spacer pipe, was used for directional injection of sealants selected for the conditions of the North Komsomolskoye field into the water cut zone of the horizontal wellbore. The results of pilot field tests indicate that there is a prospect of using water-and-gas shutoff technologies to limit water and gas inflow at the North Komsomolskoye field.
{"title":"Water-and-Gas Shutoff Technologies in Horizontal Wells on North Komsomolskoe Field: Screening and Successful Trial","authors":"T. E. Nigmatullin, Vladislav Yurievich Nikulin, A. R. Shaymardanov, R. R. Mukminov, Alexandr Yurievich Ivanov, Marat Edgarovich Akhmadullin, Dzheykhun Soltanov","doi":"10.2118/206496-ms","DOIUrl":"https://doi.org/10.2118/206496-ms","url":null,"abstract":"\u0000 The article describes the choosing a water-and-gas shutoff technology in horizontal wells (HW) drilled in terrigenous reservoirs of the North Komsomolskoye field. The well completion system is characterized by the use of liners equipped with external liner packers and inflow control devices (ICD). To solve the problem, the world experience in the use the water-and-gas shutoff technologies in HW was studied. A matrix for choosing a technology with the use of technical means and combined effect was developed based on the type of isolated fluid, the type of reservoir and the method of well completion. The technology of installing a straddle system with cup packers and a blind inter-packer pipe in a horizontal wellbore was selected to increase the success of work on isolating the inflow of water and gas in difficult geological conditions of the North Komsomolskoye field. The technology was successfully tested: a producing well with almost 100% water cut was return to effective production. A similar straddle system, but with a perforated spacer pipe, was used for directional injection of sealants selected for the conditions of the North Komsomolskoye field into the water cut zone of the horizontal wellbore. The results of pilot field tests indicate that there is a prospect of using water-and-gas shutoff technologies to limit water and gas inflow at the North Komsomolskoye field.","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":"86275562","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}
Nikita Vladislavovich Dubinya, S. Tikhotskiy, S. Fomichev, S. Golovin
The paper presents an algorithm for the search of the optimal frilling trajectory for a deviated well which is applicable for development of naturally fractured reservoirs. Criterion for identifying the optimal trajectory is the feature of the current study – optimal trajectory is chosen from the perspective of maximizing the positive effect related to activation of natural fractures in well surrounding rock masses caused by changes of the rocks stress-strain state due to drilling process. Drilling of a deviated well is shown to lead to the process of natural fractures in the vicinity of the well becoming hydraulically conductive due to drilling. The paper investigates the main natural factors – tectonic stresses and fluid pressure – and drilling parameters – drilling trajectory and mud pressure – influencing the number and variety of natural fractures being activated due to drilling process. An algorithm of finding the optimal drilling parameters from the perspective of natural fractures activation is proposed as well. Different theoretical scenarios are considered to formulate the general recommendations on drilling trajectory choice according to estimations of stress state of the reservoir. These estimations can be provided based on results of three- and four-dimensional geomechanical modeling. Such modeling may be completed as well for constructing geomechanically consistent natural fracture model which can be used to optimize drilling trajectories during exploration and development of certain objects. The paper presents a detailed algorithm of constructing such fracture models and deviated wells trajectories optimization. The results presented in the paper and given recommendations may be used to enhance drilling efficiency for reservoirs characterized by considerable contribution of natural fractures into filtration processes.
{"title":"Usage of Geomechanically Consistent Fracture Model for Drilling Deviated Wells","authors":"Nikita Vladislavovich Dubinya, S. Tikhotskiy, S. Fomichev, S. Golovin","doi":"10.2118/206559-ms","DOIUrl":"https://doi.org/10.2118/206559-ms","url":null,"abstract":"\u0000 The paper presents an algorithm for the search of the optimal frilling trajectory for a deviated well which is applicable for development of naturally fractured reservoirs. Criterion for identifying the optimal trajectory is the feature of the current study – optimal trajectory is chosen from the perspective of maximizing the positive effect related to activation of natural fractures in well surrounding rock masses caused by changes of the rocks stress-strain state due to drilling process. Drilling of a deviated well is shown to lead to the process of natural fractures in the vicinity of the well becoming hydraulically conductive due to drilling. The paper investigates the main natural factors – tectonic stresses and fluid pressure – and drilling parameters – drilling trajectory and mud pressure – influencing the number and variety of natural fractures being activated due to drilling process. An algorithm of finding the optimal drilling parameters from the perspective of natural fractures activation is proposed as well. Different theoretical scenarios are considered to formulate the general recommendations on drilling trajectory choice according to estimations of stress state of the reservoir. These estimations can be provided based on results of three- and four-dimensional geomechanical modeling. Such modeling may be completed as well for constructing geomechanically consistent natural fracture model which can be used to optimize drilling trajectories during exploration and development of certain objects. The paper presents a detailed algorithm of constructing such fracture models and deviated wells trajectories optimization. The results presented in the paper and given recommendations may be used to enhance drilling efficiency for reservoirs characterized by considerable contribution of natural fractures into filtration processes.","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":"75069645","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, B. Ganiev, A. Lutfullin, I. Farkhutdinov, M. Garnyshev, R. Farakhova, Alfiya Nurimanovna Mustafina
The paper presents a practical case of production performance analysis at one of the mature waterflood oil fields located at the Volga-Ural oil basin with a large number of wells. It is a big challenge to analyse such a large production history and requires a systematic approach. The main production complication is quite common for mature waterflood projects and includes non-uniform sweep, complicated by thief injection and thief water production. The main challenge is to locate the misperforming wells and address their complications. With the particular asset, the conventional single production analysis techniques (oil production trend, watercut trend, reservoir and bottom-hole pressure trend, productivity trend, conventional pressure build-up surveys and production logging) in the vast majority of cases were not capable of qualifying the well performance and assessing of remaining reserves status. The performance analysis of such an asset should be enhanced with new diagnostic tools and modern methods of data integration. The current study has made a choice in favor of using a PRIME analysis which is multi-parametric analytical workflow based on a set of conventional and non-conventional diagnostic metrics. The most effective diagnostics in this study have happened to be those are based on 3D dynamic micro-models, which are auto-generated from the reservoir data logs. PRIME also provided useful insights on well performance, formation properties and the current conditions of drained reserves which helped to select the candidates for infill drilling, pressure maintenance, workovers, production target adjustments and additional surveillance. The paper illustrates the entire PRIME workflow, starting from the top-level field data analysis, all the way to generating a summary table containing well diagnostics, justifications and recommendations.
{"title":"Production Performance Analysis of Volga-Ural Mature Waterflood with PRIME Diagnostic Metrics","authors":"A. Aslanyan, B. Ganiev, A. Lutfullin, I. Farkhutdinov, M. Garnyshev, R. Farakhova, Alfiya Nurimanovna Mustafina","doi":"10.2118/206513-ms","DOIUrl":"https://doi.org/10.2118/206513-ms","url":null,"abstract":"\u0000 The paper presents a practical case of production performance analysis at one of the mature waterflood oil fields located at the Volga-Ural oil basin with a large number of wells. It is a big challenge to analyse such a large production history and requires a systematic approach.\u0000 The main production complication is quite common for mature waterflood projects and includes non-uniform sweep, complicated by thief injection and thief water production. The main challenge is to locate the misperforming wells and address their complications.\u0000 With the particular asset, the conventional single production analysis techniques (oil production trend, watercut trend, reservoir and bottom-hole pressure trend, productivity trend, conventional pressure build-up surveys and production logging) in the vast majority of cases were not capable of qualifying the well performance and assessing of remaining reserves status. The performance analysis of such an asset should be enhanced with new diagnostic tools and modern methods of data integration.\u0000 The current study has made a choice in favor of using a PRIME analysis which is multi-parametric analytical workflow based on a set of conventional and non-conventional diagnostic metrics. The most effective diagnostics in this study have happened to be those are based on 3D dynamic micro-models, which are auto-generated from the reservoir data logs.\u0000 PRIME also provided useful insights on well performance, formation properties and the current conditions of drained reserves which helped to select the candidates for infill drilling, pressure maintenance, workovers, production target adjustments and additional surveillance.\u0000 The paper illustrates the entire PRIME workflow, starting from the top-level field data analysis, all the way to generating a summary table containing well diagnostics, justifications and recommendations.","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":"79243029","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. Vakhin, I. Mukhamatdinov, F. Aliev, Dmitriy F. Feoktistov, S. Sitnov, M. Gafurov, I. Minkhanov, M. Varfolomeev, D. Nurgaliev, I. Simakov, Azat A. Latypov, O. Petrashov, Aleksey V. Solovev, Georgiy Sansiev
A nickel-based catalyst precursor has been synthesized for in-situ upgrading of heavy crude oil that is capable of increasing the efficiency of steam stimulation techniques. The precursor activation occurs due to the decomposition of nickel tallate under hydrothermal conditions. The aim of this study is to analyze the efficiency of in-situ catalytic upgrading of heavy oil from laboratory scale experiments to the field-scale implementation in Boca de Jaruco reservoir. The proposed catalytic composition for in-reservoir chemical transformation of heavy oil and natural bitumen is composed of oil-soluble nickel compound and organic hydrogen donor solvent. The nickel-based catalytic composition in laboratory-scale hydrothermal conditions at 300°С and 90 bars demonstrated a high performance; the content of asphaltenes was reduced from 22% to 7 wt.%. The viscosity of crude oil was also reduced by three times. The technology for industrial-scale production of catalyst precursor was designed and the first pilot batch with a mass of 12 ton was achieved. A «Cyclic steam stimulation» technology was modified in order to deliver the catalytic composition to the pay zones of Boca de Jaruco reservoir (Cuba). The active forms of catalyst precursors are nanodispersed mixed oxides and sulfides of nickel. The pilot test of catalyst injection was carried out in bituminous carbonate formation M, in Boca de Jaruco reservoir (Cuba). The application of catalytic composition provided increase in cumulative oil production and incremental oil recovery in contrast to the previous cycle (without catalyst) is 170% up to date (the effect is in progress). After injection of catalysts, more than 200 samples from production well were analyzed in laboratory. Based on the physical and chemical properties of investigated samples and considering the excellent oil recovery coefficient it is decided to expand the industrial application of catalysts in the given reservoir. The project is scheduled on the fourth quarter of 2021.
合成了一种镍基催化剂前驱体，用于重质原油原位提质，能够提高蒸汽增产技术的效率。前驱体活化是由于高酸镍在水热条件下的分解。本研究的目的是分析Boca de Jaruco油藏重油原位催化提质从实验室规模实验到现场规模实施的效率。提出的稠油和天然沥青储层化学转化催化组合物为油溶性镍化合物和有机氢供体溶剂。在实验室规模的水热条件下，在300°С和90 bar条件下，镍基催化组合物表现出良好的性能;沥青质含量由22%降至7%。原油粘度也降低了三分之一。设计了催化剂前驱体的工业化生产工艺，实现了第一批12吨的中试生产。为了将催化成分输送到Boca de Jaruco油藏(古巴)的产层，对“循环蒸汽增产”技术进行了改进。催化剂前驱体的活性形式是纳米分散的镍的混合氧化物和硫化物。在Boca de Jaruco油藏M碳酸沥青地层中进行了催化剂注入中试。迄今为止，与上一个周期(不使用催化剂)相比，催化组合物的应用使累计产油量和产油量增加了170%(效果仍在继续)。注入催化剂后，对200多口生产井样品进行了实验室分析。根据所研究样品的物理化学性质，并考虑到其优异的采收率系数，决定在给定油藏中扩大催化剂的工业应用。该项目计划于2021年第四季度启动。
{"title":"Industrial Application of Nickel Tallate Catalyst During Cyclic Steam Stimulation in Boca De Jaruco Reservoir","authors":"A. Vakhin, I. Mukhamatdinov, F. Aliev, Dmitriy F. Feoktistov, S. Sitnov, M. Gafurov, I. Minkhanov, M. Varfolomeev, D. Nurgaliev, I. Simakov, Azat A. Latypov, O. Petrashov, Aleksey V. Solovev, Georgiy Sansiev","doi":"10.2118/206419-ms","DOIUrl":"https://doi.org/10.2118/206419-ms","url":null,"abstract":"\u0000 A nickel-based catalyst precursor has been synthesized for in-situ upgrading of heavy crude oil that is capable of increasing the efficiency of steam stimulation techniques. The precursor activation occurs due to the decomposition of nickel tallate under hydrothermal conditions. The aim of this study is to analyze the efficiency of in-situ catalytic upgrading of heavy oil from laboratory scale experiments to the field-scale implementation in Boca de Jaruco reservoir. The proposed catalytic composition for in-reservoir chemical transformation of heavy oil and natural bitumen is composed of oil-soluble nickel compound and organic hydrogen donor solvent. The nickel-based catalytic composition in laboratory-scale hydrothermal conditions at 300°С and 90 bars demonstrated a high performance; the content of asphaltenes was reduced from 22% to 7 wt.%. The viscosity of crude oil was also reduced by three times.\u0000 The technology for industrial-scale production of catalyst precursor was designed and the first pilot batch with a mass of 12 ton was achieved. A «Cyclic steam stimulation» technology was modified in order to deliver the catalytic composition to the pay zones of Boca de Jaruco reservoir (Cuba). The active forms of catalyst precursors are nanodispersed mixed oxides and sulfides of nickel.\u0000 The pilot test of catalyst injection was carried out in bituminous carbonate formation M, in Boca de Jaruco reservoir (Cuba). The application of catalytic composition provided increase in cumulative oil production and incremental oil recovery in contrast to the previous cycle (without catalyst) is 170% up to date (the effect is in progress). After injection of catalysts, more than 200 samples from production well were analyzed in laboratory. Based on the physical and chemical properties of investigated samples and considering the excellent oil recovery coefficient it is decided to expand the industrial application of catalysts in the given reservoir. The project is scheduled on the fourth quarter of 2021.","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":"87238413","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. Yudin, AbdulMuqtadir Khan, R. Romanovskii, A. Alekseev, Dmitry Abdrazakov
The oilfield industry is rapidly changing towards reduced CO2 emissions and sustainability. Although hydrocarbons are expected to remain the leading source for global energy, costs to produce them may become prohibitive unless new breakthrough in technology is established. Fortunately, the digital revolution in the IT industry continues at an accelerating pace. A digital stimulation approach for tight formations is presented, using the achievements of one industry to solve the challenges of another. The fracture hydrodynamics and in-situ kinetics model is incorporated in the advanced simulator together with the detailed multiphysics models based on acid systems digitization, including rheology and fluid- carbonate interactions data obtained from the laboratory experiments. Digitization of fluid-rock interaction and fluid leakoff was performed using a coreflooding setup that allowed pumping concentrated acids in core samples at high-pressure/high-temperature (HP/HT) conditions. Varying the testing parameters across a broad range allowed refining the model coefficients in the simulator to obtain high accuracy in the predicted results. The digital slot concept was used to validate physical models in an iterative experimental approach. The software proved efficient at providing validation of multiphysics models used together with advanced slurry transport in the simulator. The fine computational grid allowed accurate predictions of the fracture geometry, etched width, and channel conductivity, resulting in realistic well productivity anticipations. Since multiple fluid systems of the acid stimulation portfolio were digitized and incorporated into the simulator, it was possible to optimize complex acid fracturing designs in the real field operations that included retarded single-phase and multiphase acid systems, self-diverting viscoelastic acids, and fiber- based diverting systems. Several case studies from multiple areas and reservoirs from Caspian and Middle East areas have demonstrated extremely positive oil and gas production results with reduced acid volumes with the digital stimulation workflow compared to conventionally stimulated offset wells. The digital stimulation workflow brings a new approach to acid fracturing optimization based on an integrated cycle in which high-resolution data from several sources are processed by powerful computing capacities. Starting from digitizing acid reactions with the core samples, through digitized rheology and particle transport in multiphysics models, an advanced numerical simulator tailors an optimum design from a number of acid system options, pumping rates, additive concentrations, and stage volumes to achieve best geometry of etched channels inside a fracture.
{"title":"Control Over the Fracture in Carbonate Reservoirs as a Result of an Integrated Digital Stimulation Approach to Core Testing and Modeling","authors":"A. Yudin, AbdulMuqtadir Khan, R. Romanovskii, A. Alekseev, Dmitry Abdrazakov","doi":"10.2118/206636-ms","DOIUrl":"https://doi.org/10.2118/206636-ms","url":null,"abstract":"The oilfield industry is rapidly changing towards reduced CO2 emissions and sustainability. Although hydrocarbons are expected to remain the leading source for global energy, costs to produce them may become prohibitive unless new breakthrough in technology is established. Fortunately, the digital revolution in the IT industry continues at an accelerating pace. A digital stimulation approach for tight formations is presented, using the achievements of one industry to solve the challenges of another. The fracture hydrodynamics and in-situ kinetics model is incorporated in the advanced simulator together with the detailed multiphysics models based on acid systems digitization, including rheology and fluid- carbonate interactions data obtained from the laboratory experiments. Digitization of fluid-rock interaction and fluid leakoff was performed using a coreflooding setup that allowed pumping concentrated acids in core samples at high-pressure/high-temperature (HP/HT) conditions. Varying the testing parameters across a broad range allowed refining the model coefficients in the simulator to obtain high accuracy in the predicted results. The digital slot concept was used to validate physical models in an iterative experimental approach. The software proved efficient at providing validation of multiphysics models used together with advanced slurry transport in the simulator. The fine computational grid allowed accurate predictions of the fracture geometry, etched width, and channel conductivity, resulting in realistic well productivity anticipations. Since multiple fluid systems of the acid stimulation portfolio were digitized and incorporated into the simulator, it was possible to optimize complex acid fracturing designs in the real field operations that included retarded single-phase and multiphase acid systems, self-diverting viscoelastic acids, and fiber- based diverting systems. Several case studies from multiple areas and reservoirs from Caspian and Middle East areas have demonstrated extremely positive oil and gas production results with reduced acid volumes with the digital stimulation workflow compared to conventionally stimulated offset wells. The digital stimulation workflow brings a new approach to acid fracturing optimization based on an integrated cycle in which high-resolution data from several sources are processed by powerful computing capacities. Starting from digitizing acid reactions with the core samples, through digitized rheology and particle transport in multiphysics models, an advanced numerical simulator tailors an optimum design from a number of acid system options, pumping rates, additive concentrations, and stage volumes to achieve best geometry of etched channels inside a fracture.","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":"84080317","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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