Pub Date : 2021-05-24DOI: 10.3997/2214-4609.202154041
N. Shaymardanov
Summary The development of geologically complex fields with horizontal wells often requires the use of special technologies not only directly for drilling a well within the target interval, but also for well landing. This paper considers an example of the well landing special requirements with the aim of further successful drilling in the target zone in the conditions of the Filanovsky field edge area (North Caspian Offshore). The development target is the Lower Cretaceous sediments (Neocomian superstage), represented by interlayering of sandy reservoirs and clay-siltstones, changing their thickness and properties both in the northeastern and southwestern directions. The oilfield is characterized also by presence of fault zones (with amplitudes from 1 to 65 m). In addition to these geological and structural uncertainties during horizontal wells drilling on the edge parts of the structure (fold wings), significant structural angles cause additional complexity. One more important condition for the successful well landing is the fluid contacts crossing in definite parts of the section. Ultra-Deep Electromagnetic Logging While Drilling Mapping Technology was used to solve successfully all uncertainties and tasks.
{"title":"The importance of pinpoint horizontal well landing","authors":"N. Shaymardanov","doi":"10.3997/2214-4609.202154041","DOIUrl":"https://doi.org/10.3997/2214-4609.202154041","url":null,"abstract":"Summary The development of geologically complex fields with horizontal wells often requires the use of special technologies not only directly for drilling a well within the target interval, but also for well landing. This paper considers an example of the well landing special requirements with the aim of further successful drilling in the target zone in the conditions of the Filanovsky field edge area (North Caspian Offshore). The development target is the Lower Cretaceous sediments (Neocomian superstage), represented by interlayering of sandy reservoirs and clay-siltstones, changing their thickness and properties both in the northeastern and southwestern directions. The oilfield is characterized also by presence of fault zones (with amplitudes from 1 to 65 m). In addition to these geological and structural uncertainties during horizontal wells drilling on the edge parts of the structure (fold wings), significant structural angles cause additional complexity. One more important condition for the successful well landing is the fluid contacts crossing in definite parts of the section. Ultra-Deep Electromagnetic Logging While Drilling Mapping Technology was used to solve successfully all uncertainties and tasks.","PeriodicalId":105144,"journal":{"name":"Horizontal Wells 2021","volume":"264 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-05-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114470571","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2021-05-24DOI: 10.3997/2214-4609.202154010
V. Noskevich, V. Gorshkov
Summary The article presents the results of ground penetrating radar (GPR) researches of the gas subway pipeline, which was passed under the river by horizontal drilling. GPR method allowed to distinguish the layers boundaries in more detail than drilling data, and also found an anomalous zone with a high-frequency "ringing", corresponding to a metal object that damaged the upper part of the gas pipeline.
{"title":"Investigation of state of the gas pipeline part under the Vym River","authors":"V. Noskevich, V. Gorshkov","doi":"10.3997/2214-4609.202154010","DOIUrl":"https://doi.org/10.3997/2214-4609.202154010","url":null,"abstract":"Summary The article presents the results of ground penetrating radar (GPR) researches of the gas subway pipeline, which was passed under the river by horizontal drilling. GPR method allowed to distinguish the layers boundaries in more detail than drilling data, and also found an anomalous zone with a high-frequency \"ringing\", corresponding to a metal object that damaged the upper part of the gas pipeline.","PeriodicalId":105144,"journal":{"name":"Horizontal Wells 2021","volume":"48 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-05-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130645709","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2021-05-24DOI: 10.3997/2214-4609.202154031
A. Senkov, O. Abramenko, V. Nagimov, A. Trusov
Summary Sustained Annulus Pressure (SAP) monitoring on offshore stationary platforms plays an important role in the development of oilfields with the massive gas cap. Conventional SAP diagnostic techniques is significantly limited primarily by the complexity of unwanted flowpaths in annular space and the presence of multiple pipe barriers. Multisensory passive acoustics is the novel approach evaluating SAP. Several accurately synchronized high-definition acoustic sensors measuring acoustics wave time arrival shift of the signal generating by active flow source. To take into account acoustic wave reflections in multiple strings of well construction 3D modelling of acoustic propagation is applied. The logging campaign of five wells was surveyed using slickline. Both conventional single sensor and multisensory spectral acoustics were used in the same toolstring. The multisensory acoustic data indicated active SAP sources and estimated the distance to the SAP source and flowpath separately, differentiation of that is impossible using single sensor spectral acoustics data. As a result of the campaign multisensory passive spectral acoustic instrument demonstrated additional important features on SAP source identification over conventional single sensor spectral acoustics. The most important feature is the differentiation of SAP source and flowpaths behind multiple casings. This significantly improves workover planning on SAP source isolation
{"title":"New Prospects of SAP Investigation using Multisensory Passive Spectral Acoustics","authors":"A. Senkov, O. Abramenko, V. Nagimov, A. Trusov","doi":"10.3997/2214-4609.202154031","DOIUrl":"https://doi.org/10.3997/2214-4609.202154031","url":null,"abstract":"Summary Sustained Annulus Pressure (SAP) monitoring on offshore stationary platforms plays an important role in the development of oilfields with the massive gas cap. Conventional SAP diagnostic techniques is significantly limited primarily by the complexity of unwanted flowpaths in annular space and the presence of multiple pipe barriers. Multisensory passive acoustics is the novel approach evaluating SAP. Several accurately synchronized high-definition acoustic sensors measuring acoustics wave time arrival shift of the signal generating by active flow source. To take into account acoustic wave reflections in multiple strings of well construction 3D modelling of acoustic propagation is applied. The logging campaign of five wells was surveyed using slickline. Both conventional single sensor and multisensory spectral acoustics were used in the same toolstring. The multisensory acoustic data indicated active SAP sources and estimated the distance to the SAP source and flowpath separately, differentiation of that is impossible using single sensor spectral acoustics data. As a result of the campaign multisensory passive spectral acoustic instrument demonstrated additional important features on SAP source identification over conventional single sensor spectral acoustics. The most important feature is the differentiation of SAP source and flowpaths behind multiple casings. This significantly improves workover planning on SAP source isolation","PeriodicalId":105144,"journal":{"name":"Horizontal Wells 2021","volume":"47 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-05-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125058058","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2021-05-24DOI: 10.3997/2214-4609.202154006
E. Grishina, M. I. Kremenetsky
Summary The Paper presented usage of Well Testing and Production logging in Horizontal wells in low permeability reservoirs. The obtained test results were reviewed in order to estimate parameters of each individual fracture and reservoir permeability using production contribution of each fracture by PLT and bottom-hole pressure and surface liquid rate of tested wells. Optimal testing technology and interpretation methodology is justified by numerical modeling.
{"title":"Integrated approach to well test and production log analysis interpretation of multiple hydraulically fractured horizontal wells in low permeability heterogeneous formation","authors":"E. Grishina, M. I. Kremenetsky","doi":"10.3997/2214-4609.202154006","DOIUrl":"https://doi.org/10.3997/2214-4609.202154006","url":null,"abstract":"Summary The Paper presented usage of Well Testing and Production logging in Horizontal wells in low permeability reservoirs. The obtained test results were reviewed in order to estimate parameters of each individual fracture and reservoir permeability using production contribution of each fracture by PLT and bottom-hole pressure and surface liquid rate of tested wells. Optimal testing technology and interpretation methodology is justified by numerical modeling.","PeriodicalId":105144,"journal":{"name":"Horizontal Wells 2021","volume":"132 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-05-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134129281","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2021-05-24DOI: 10.3997/2214-4609.202154027
D. Malyutin, O. Grachev, A. V. Bekmachev, A. Puchkov, Ya.N. Smyshlyaev, I. Oparin
Summary This thesis presents the technology for assessing the risks of mud losses during drilling using 1D geomechanical modeling in conjunction with the seismic interpretation data MOGT-3D. Based on a combination of seismic and geomechanical data, a methodology has been developed for estimating the equivalent circulating density values, above which the mud losses will appear during drilling, which makes it possible to predict drilling risks and provide measures to prevent them without increasing the cost of drilling. In the examples considered, the forecast of mud losses by this method has a 72% confirmation (21 out of 29 wells). In order to further improve the technique, a number of measures have been proposed, including, conducting special methods of geophysical well logging to determine the nature of zones with increased mud loss risks and clarifying the direction of maximum horizontal stress, as well as performing leak-off tests (LOT and XLOT) for estimations of mud loss and hydraulic fracture pressures. The seismic-geomechanical model constructed according to the proposed method can be used to solve other equally important tasks: search for zones of increased reservoir properties, the location of the ports of multistage hydraulic fracturing, risk assessment of increased wear of bits and others.
{"title":"Integration of geomechanical and seismic data for losses predictions while drilling horizontal wells","authors":"D. Malyutin, O. Grachev, A. V. Bekmachev, A. Puchkov, Ya.N. Smyshlyaev, I. Oparin","doi":"10.3997/2214-4609.202154027","DOIUrl":"https://doi.org/10.3997/2214-4609.202154027","url":null,"abstract":"Summary This thesis presents the technology for assessing the risks of mud losses during drilling using 1D geomechanical modeling in conjunction with the seismic interpretation data MOGT-3D. Based on a combination of seismic and geomechanical data, a methodology has been developed for estimating the equivalent circulating density values, above which the mud losses will appear during drilling, which makes it possible to predict drilling risks and provide measures to prevent them without increasing the cost of drilling. In the examples considered, the forecast of mud losses by this method has a 72% confirmation (21 out of 29 wells). In order to further improve the technique, a number of measures have been proposed, including, conducting special methods of geophysical well logging to determine the nature of zones with increased mud loss risks and clarifying the direction of maximum horizontal stress, as well as performing leak-off tests (LOT and XLOT) for estimations of mud loss and hydraulic fracture pressures. The seismic-geomechanical model constructed according to the proposed method can be used to solve other equally important tasks: search for zones of increased reservoir properties, the location of the ports of multistage hydraulic fracturing, risk assessment of increased wear of bits and others.","PeriodicalId":105144,"journal":{"name":"Horizontal Wells 2021","volume":"23 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-05-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131212031","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2021-05-24DOI: 10.3997/2214-4609.202154032
T. Solovyev
Summary The article also describes general information about the inflow control devices technology, their characteristics and problems that the operators user may encounter when using one or another element of high-tech completion, gives reasons for the use of autonomous inflow control devices at the considered development object. Analysis of field data and PLT and well logs results revealed that the devices actually work and help to limit water and gas compared to wells that are equipped only with wire filters without inflow control, and also begin to form a unified strategy and concept of well completion based on the data The results of the work show that currently the use of AFCD for the project is favorable, and the completion of wells without flow control in these conditions is impractical.
{"title":"An Integrated Approach for Application and Operation evaluation of Autonomous Inflow Control Devices in Horizontal and Multilateral wells","authors":"T. Solovyev","doi":"10.3997/2214-4609.202154032","DOIUrl":"https://doi.org/10.3997/2214-4609.202154032","url":null,"abstract":"Summary The article also describes general information about the inflow control devices technology, their characteristics and problems that the operators user may encounter when using one or another element of high-tech completion, gives reasons for the use of autonomous inflow control devices at the considered development object. Analysis of field data and PLT and well logs results revealed that the devices actually work and help to limit water and gas compared to wells that are equipped only with wire filters without inflow control, and also begin to form a unified strategy and concept of well completion based on the data The results of the work show that currently the use of AFCD for the project is favorable, and the completion of wells without flow control in these conditions is impractical.","PeriodicalId":105144,"journal":{"name":"Horizontal Wells 2021","volume":"46 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-05-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122571323","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2021-05-24DOI: 10.3997/2214-4609.202154070
N. V. Krivosheev, N. N. Krivosheeva, R. A. Shadchnev, D. Sharapov
Summary Drilling of offshore oil and gas wells remains one of the most important activities of the Russian oil and gas industry in the coming years. The issue of geological exploration and the profitability of the development of offshore fields is still acute. The D33 field is located on the shelf of the Baltic Sea within the boundaries of the Baltic license area. The depth of the sea within the field varies from 60 to 80 m. The purpose of the work is to increase the efficiency of drilling wells and the profitability of the development of offshore fields by optimizing the design of double-barrel wells. Several schemes of drilling of the D33 field with the reconstruction of the well trajectories are proposed. Technical and economic calculations were performed, which resulted in optimization of the design of double-barrel wells at the D33 offshore field. The cost of well construction was estimated according to the basic and optimized version, the results showed that the savings in the construction of a well according to the optimized version will be 5.5%.
{"title":"Feasibility study for optimizing the design of double-barrel wells of the D33 field on the Baltic Sea shelf","authors":"N. V. Krivosheev, N. N. Krivosheeva, R. A. Shadchnev, D. Sharapov","doi":"10.3997/2214-4609.202154070","DOIUrl":"https://doi.org/10.3997/2214-4609.202154070","url":null,"abstract":"Summary Drilling of offshore oil and gas wells remains one of the most important activities of the Russian oil and gas industry in the coming years. The issue of geological exploration and the profitability of the development of offshore fields is still acute. The D33 field is located on the shelf of the Baltic Sea within the boundaries of the Baltic license area. The depth of the sea within the field varies from 60 to 80 m. The purpose of the work is to increase the efficiency of drilling wells and the profitability of the development of offshore fields by optimizing the design of double-barrel wells. Several schemes of drilling of the D33 field with the reconstruction of the well trajectories are proposed. Technical and economic calculations were performed, which resulted in optimization of the design of double-barrel wells at the D33 offshore field. The cost of well construction was estimated according to the basic and optimized version, the results showed that the savings in the construction of a well according to the optimized version will be 5.5%.","PeriodicalId":105144,"journal":{"name":"Horizontal Wells 2021","volume":"28 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-05-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123474380","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2021-05-24DOI: 10.3997/2214-4609.202154062
Y.A. Podchuvalova, I. Chameev, E. Sherstoboev, E. Borisov, V.N. Grischuk
Summary The article presents an approach that allows to evaluate the efficiency of gas re-injection into the layers of the Novoportovskoe Field, detect the reasons of injection rate decrease, and analyze the impact of gas injection on the development of the oil layers. The method is based on gas-dynamic tests of wells. The development of the field began in the absence of outside gas infrastructure. For the purpose of rational utilization of associated gas, until the outside gas infrastructure is ready, it was decided to re-inject gas into the main reservoirs. The reservoirs are represented by fringes of the marginal and underlying type. There is a risk of a gas breakthrough to the producing wells. It is necessary to optimize the re-injection of gas in order to equalize the reservoir pressure profile and increase oil production. The current task is to monitor the re-injection of gas, targeted management of gas injection wells, which will allow to inject the necessary volumes and get additional oil production. Based on the assessment, measures are proposed to recover injection coefficients. Timely diagnosis of the causes ensures the rational use of associated gas by the planned gas injection well stock.
{"title":"Gas-dynamic methods of well research as a tool for complex improvement of the efficiency of gas re-injection into the gas cap of the Novoportovskoe Oil and Gas Condensate Field","authors":"Y.A. Podchuvalova, I. Chameev, E. Sherstoboev, E. Borisov, V.N. Grischuk","doi":"10.3997/2214-4609.202154062","DOIUrl":"https://doi.org/10.3997/2214-4609.202154062","url":null,"abstract":"Summary The article presents an approach that allows to evaluate the efficiency of gas re-injection into the layers of the Novoportovskoe Field, detect the reasons of injection rate decrease, and analyze the impact of gas injection on the development of the oil layers. The method is based on gas-dynamic tests of wells. The development of the field began in the absence of outside gas infrastructure. For the purpose of rational utilization of associated gas, until the outside gas infrastructure is ready, it was decided to re-inject gas into the main reservoirs. The reservoirs are represented by fringes of the marginal and underlying type. There is a risk of a gas breakthrough to the producing wells. It is necessary to optimize the re-injection of gas in order to equalize the reservoir pressure profile and increase oil production. The current task is to monitor the re-injection of gas, targeted management of gas injection wells, which will allow to inject the necessary volumes and get additional oil production. Based on the assessment, measures are proposed to recover injection coefficients. Timely diagnosis of the causes ensures the rational use of associated gas by the planned gas injection well stock.","PeriodicalId":105144,"journal":{"name":"Horizontal Wells 2021","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-05-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132582230","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2021-05-24DOI: 10.3997/2214-4609.202154084
E. Radionova, A. Alekseev
Summary The technology of a modern approach to the calculation of hydrocarbon reserves and risk assessment when drilling horizontal wells using all geological and geophysical information
利用所有地质和地球物理信息进行水平井油气储量计算和风险评估的现代方法技术
{"title":"The technology of a modern approach to the calculation of hydrocarbon reserves and risk assessment when drilling horizontal wells using all geological and geophysical information","authors":"E. Radionova, A. Alekseev","doi":"10.3997/2214-4609.202154084","DOIUrl":"https://doi.org/10.3997/2214-4609.202154084","url":null,"abstract":"Summary The technology of a modern approach to the calculation of hydrocarbon reserves and risk assessment when drilling horizontal wells using all geological and geophysical information","PeriodicalId":105144,"journal":{"name":"Horizontal Wells 2021","volume":"4 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-05-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133528042","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2021-05-24DOI: 10.3997/2214-4609.202154021
S. A. Moiseev, Y. Plitkina, D. P. Patrakov, A. Glebov
Summary The challenges of developing the Tyumen Formation reserves are associated with the following features: thick oil column, high heterogeneity, abnormally low permeability, and a low degree of knowledge. Historically, the development of the Tyumen Formation has been uneconomic due to low startup oil rates and high decline rates. The first active phase of development began in 2009, due to recompletions at the Talinsky license block and drilling of directional wells with hydraulic fracturing at the Em-Yegovsky license block. Those measures resulted in recoveries of less than 2% of the initial recoverable reserves. The next stage started in 2013–2015, when a pilot project of “horizontal wells with hydraulic fracturing” was successfully implemented at the Em-Egovsky license block. Together with the tax incentives to the MET rate, this made it possible to significantly expand the zones of economic drilling and ensure an increase in oil production. Based on successful practices at the Em-Egovsky license block, since 2017, the HzW + MSHF technology has been replicated at the Kamenny and Talinsky license blocks. In the next 20 years, it is planned to drill about 5,000 wells in the Tyumen Formation which will increase production by more than five times. In 2020, a pilot project was implemented to increase the length of a horizontal well (up to 1,200 m) and the number of hydraulic fracturing stages (up to 12). Note that the current tax incentives will not allow the full involvement of the Tyumen Formation reserves into development - when moving into zones of poorer quality, the development economics decreases. By the time the tax benefit expires (2030–2035), 40% of planned wells will be drilled, the recoveries from initial recoverable reserves will not exceed 20%. Further growth and maintenance of oil production will require additional tax incentives.
{"title":"Improving Development Efficiency of Hard-to-Recover Reserves of Tyumen Formation (JK2-9) at Krasnoleninsky Field","authors":"S. A. Moiseev, Y. Plitkina, D. P. Patrakov, A. Glebov","doi":"10.3997/2214-4609.202154021","DOIUrl":"https://doi.org/10.3997/2214-4609.202154021","url":null,"abstract":"Summary The challenges of developing the Tyumen Formation reserves are associated with the following features: thick oil column, high heterogeneity, abnormally low permeability, and a low degree of knowledge. Historically, the development of the Tyumen Formation has been uneconomic due to low startup oil rates and high decline rates. The first active phase of development began in 2009, due to recompletions at the Talinsky license block and drilling of directional wells with hydraulic fracturing at the Em-Yegovsky license block. Those measures resulted in recoveries of less than 2% of the initial recoverable reserves. The next stage started in 2013–2015, when a pilot project of “horizontal wells with hydraulic fracturing” was successfully implemented at the Em-Egovsky license block. Together with the tax incentives to the MET rate, this made it possible to significantly expand the zones of economic drilling and ensure an increase in oil production. Based on successful practices at the Em-Egovsky license block, since 2017, the HzW + MSHF technology has been replicated at the Kamenny and Talinsky license blocks. In the next 20 years, it is planned to drill about 5,000 wells in the Tyumen Formation which will increase production by more than five times. In 2020, a pilot project was implemented to increase the length of a horizontal well (up to 1,200 m) and the number of hydraulic fracturing stages (up to 12). Note that the current tax incentives will not allow the full involvement of the Tyumen Formation reserves into development - when moving into zones of poorer quality, the development economics decreases. By the time the tax benefit expires (2030–2035), 40% of planned wells will be drilled, the recoveries from initial recoverable reserves will not exceed 20%. Further growth and maintenance of oil production will require additional tax incentives.","PeriodicalId":105144,"journal":{"name":"Horizontal Wells 2021","volume":"114 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2021-05-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133801722","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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