Most of the new fields in Western Siberia have unfavorable conditions for the development of the field, such as the presence of an extensive gas cap, the low power of oil-saturated oil rim thicknesses, and the underlying water. The field is also characterized by weakly consolidated sandstone and high-viscosity oil. For the deposition of an early breakthrough of water or gas into the wellbore, it was decided to conduct a pilot stage of project on the use of various types of completion (autonomous inflow control devices), which allow controlling the inflow along the wellbore. Formation of completion strategy requires continuous monitoring of wells, evaluation of the effectiveness of cleaning intervals after drilling, interval flow along the wellbore, as well as the detection of water or gas breakthrough areas to identify the ineffective placement of AFCD. This article presents the results of the use of autonomous flow control devices, an assessment of their effectiveness according to PLT and well logs interpretation and intellectual tracers, as well as analytical methods. 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":"Enhancing Efficiency of High-Viscosity Oil Development with Using Autonomous Flow Control Devices. Case Study in Western Siberia.","authors":"T. Solovyev","doi":"10.2118/196851-ms","DOIUrl":"https://doi.org/10.2118/196851-ms","url":null,"abstract":"\u0000 Most of the new fields in Western Siberia have unfavorable conditions for the development of the field, such as the presence of an extensive gas cap, the low power of oil-saturated oil rim thicknesses, and the underlying water. The field is also characterized by weakly consolidated sandstone and high-viscosity oil. For the deposition of an early breakthrough of water or gas into the wellbore, it was decided to conduct a pilot stage of project on the use of various types of completion (autonomous inflow control devices), which allow controlling the inflow along the wellbore. Formation of completion strategy requires continuous monitoring of wells, evaluation of the effectiveness of cleaning intervals after drilling, interval flow along the wellbore, as well as the detection of water or gas breakthrough areas to identify the ineffective placement of AFCD.\u0000 This article presents the results of the use of autonomous flow control devices, an assessment of their effectiveness according to PLT and well logs interpretation and intellectual tracers, as well as analytical methods.\u0000 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.\u0000 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\u0000 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":10977,"journal":{"name":"Day 2 Wed, October 23, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-10-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87988185","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. Sleptsov, I. Ishimov, Y. Golovatskiy, N. Mezhnova
Vertical wells drilling for development of viscous oil in formations with low oil saturated thickness and underlying water zone, usually has a poor economics due to fast water breakthrough (water coning). The wells with 300 - 400m horizontal sections with a dense placing are able to achieve high recovery factor, but have a limitations during drilling and completion and subsequent production management. The paper discusses the results of pilot works on the multilateral well construction in a highly viscous oil field with underlying water. The well designed especially for development producing intervals of bobrikovsky formation, widespread in a Volga-Ural region of Russia. Based on detailed 3D geological model of the reservoir a well with three laterals was designed, equipped with inflow control devices (ICD) with sliding sleeves to enable isolation of each wellbore. The well has high horizontal sweep efficiency with a possibility to fully manage the inflow from every lateral in case of water breakthrough. Using while drilling the deep azimuthal resistivity measurement tool allowed placing the wellbores in the top of pay zone far from water contact. According to the LWD measurements, the proper ICDs parameters were determined before well completion in order to equalize the inflow profile of the horizontal section. A significant increase in productivity and cumulative oil production of multilaterals allow to reduce wells density and ensure economic efficiency, even despite the increase in costs compared to horizontal well.
{"title":"Implementation the Multilateral Wells With ICDs for Development of Formations With High Viscosity Oil and Underlying Water Zone","authors":"D. Sleptsov, I. Ishimov, Y. Golovatskiy, N. Mezhnova","doi":"10.2118/196748-ms","DOIUrl":"https://doi.org/10.2118/196748-ms","url":null,"abstract":"\u0000 Vertical wells drilling for development of viscous oil in formations with low oil saturated thickness and underlying water zone, usually has a poor economics due to fast water breakthrough (water coning). The wells with 300 - 400m horizontal sections with a dense placing are able to achieve high recovery factor, but have a limitations during drilling and completion and subsequent production management.\u0000 The paper discusses the results of pilot works on the multilateral well construction in a highly viscous oil field with underlying water. The well designed especially for development producing intervals of bobrikovsky formation, widespread in a Volga-Ural region of Russia.\u0000 Based on detailed 3D geological model of the reservoir a well with three laterals was designed, equipped with inflow control devices (ICD) with sliding sleeves to enable isolation of each wellbore. The well has high horizontal sweep efficiency with a possibility to fully manage the inflow from every lateral in case of water breakthrough.\u0000 Using while drilling the deep azimuthal resistivity measurement tool allowed placing the wellbores in the top of pay zone far from water contact. According to the LWD measurements, the proper ICDs parameters were determined before well completion in order to equalize the inflow profile of the horizontal section. A significant increase in productivity and cumulative oil production of multilaterals allow to reduce wells density and ensure economic efficiency, even despite the increase in costs compared to horizontal well.","PeriodicalId":10977,"journal":{"name":"Day 2 Wed, October 23, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-10-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77548651","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}
C. H. Canbaz, C. Temizel, Yildiray Palabiyik, Melek Deniz-Paker, M. H. Ozyurtkan
Micellar – Polymer drive process is one of the effective, proven and widely used non-thermal EOR methods which classified under chemical flooding. The process is preferable in reservoirs that don’t have enough aquifer assistance and also in depleted reservoirs. A successful micellar-polymer flooding operation can be enabled by having correct data of parameters like reservoir pressure, mineral types in the reservoir, phase behavior of microemulsions, reservoir temperature, salinity data, buffer stability, micellar slug, and concentrations of the surfactants. In this study, A comprehensive literature review regarding on above parameters studied with field case studies worldwide. A Micellar-polymer drive process is applied on a stochastic reservoir and the optimization of the case performed by considering the mechanisms and limitations of micellar-polymer drive process, selection and design criteria, as well as the phase behavior changes during the process to have the most effective residual oil recovery. Parameters that enables an optimal recovery is described and used as optimization parameters in a full-physics commercial reservoir simulator. Typical Injection sequence that includes water flooding, polymer injection, polymer drive, polymer taper and chase water is applied for selected time periods. Changes of Oil saturation, water viscosity, adsorbed fluid, surfactant and polymer adsorption is simulated by using the optimal values of selected optimization parameters. General solution results are given with the optimal solution and all compared with the base case. It clarified that the Micellar-polymer drive optimization maximizes cumulative oil recovery in a reservoir that has a stochastically generated permeability distribution.
{"title":"Optimization of Micellar-Polymer Drive in a Stochastic Reservoir","authors":"C. H. Canbaz, C. Temizel, Yildiray Palabiyik, Melek Deniz-Paker, M. H. Ozyurtkan","doi":"10.2118/196765-ms","DOIUrl":"https://doi.org/10.2118/196765-ms","url":null,"abstract":"\u0000 Micellar – Polymer drive process is one of the effective, proven and widely used non-thermal EOR methods which classified under chemical flooding. The process is preferable in reservoirs that don’t have enough aquifer assistance and also in depleted reservoirs. A successful micellar-polymer flooding operation can be enabled by having correct data of parameters like reservoir pressure, mineral types in the reservoir, phase behavior of microemulsions, reservoir temperature, salinity data, buffer stability, micellar slug, and concentrations of the surfactants.\u0000 In this study, A comprehensive literature review regarding on above parameters studied with field case studies worldwide. A Micellar-polymer drive process is applied on a stochastic reservoir and the optimization of the case performed by considering the mechanisms and limitations of micellar-polymer drive process, selection and design criteria, as well as the phase behavior changes during the process to have the most effective residual oil recovery. Parameters that enables an optimal recovery is described and used as optimization parameters in a full-physics commercial reservoir simulator.\u0000 Typical Injection sequence that includes water flooding, polymer injection, polymer drive, polymer taper and chase water is applied for selected time periods. Changes of Oil saturation, water viscosity, adsorbed fluid, surfactant and polymer adsorption is simulated by using the optimal values of selected optimization parameters. General solution results are given with the optimal solution and all compared with the base case. It clarified that the Micellar-polymer drive optimization maximizes cumulative oil recovery in a reservoir that has a stochastically generated permeability distribution.","PeriodicalId":10977,"journal":{"name":"Day 2 Wed, October 23, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-10-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78490338","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}
Ya.G. Gorbachev, D. Chaplygin, D. Khamadaliev, Viktor Yashnev, Igor Novikov, K. Ovchinnikov, A. Katashov, E. Malyavko, K. Saprykina, Vasily Kiselev
The development of hydraulic fracturing technology began with single operations and is currently the most effective tool for increasing the productivity of wells and managing field development. Without the application of the hydraulic fracturing method, many fields would not have been successfully put into operation. For example, in the USA, hydraulic fracturing technology is used almost everywhere, which enabled an increase in the share of recoverable reserves by 25-30%. The first hydraulic fracturing in our country was carried out in 1952. After this, the number of such works increased for several years, but then declined. This was due to the industrial development of large oil fields in Western Siberia. The application of hydraulic fracturing technology was resumed in the 1980s and has been growing steadily ever since (Usachev, 1986). Horizontal drilling technologies are currently developing at a fairly rapid pace, which entails an increase in the accuracy of penetrating a given part of the formation. Multi-stage hydraulic fracturing is primarily used in the well to increase the flow rate. It is expected that in the perspective of 2019-2020, the share of horizontal drilling will reach 46-50%, which is due to plans for the intensive development of new fields in Eastern Siberia (Figure 1). Figure 1Dynamics of the number of wells completed using horizontal and controlled directional drilling in Russia in 2008–2026 (fact and forecast), units There has been a steady increase in the share of horizontal drilling with the total volume of production in Russia since 2008 (Figure 2). This indicates qualitative changes in the technological approaches of today's production companies. Figure 2Dynamics of throughput volume in production drilling in Russia in 2008–2026 (fact and forecast), mln. m. Technical solutions are required for the delivery of geophysical equipment to the horizontal section of the well for horizontal wells production logging using an electric centrifugal pump (ESP). The existing Y-tool technology allows for lowering the geophysical equipment to the coiled tubing system, therefore bypassing the ESP system in close proximity to well operation mode, but this increases the well completion cost by 25%. Along with the conventional methods of horizontal wells production logging such as PLT logging, oil producing companies are increasingly beginning to apply innovative methods based on marker technology. This method applies the flow indicators that are able to trace the flow of each phase into the well separately and continuously for several years. The objective of this article is to describe the results of using the fluorescent microsphere method, taking into account their long-term use for estimating the inflow structure from each port of hydraulic fracturing in horizontal wells. This helps users to avoid risky and costly downhole operations at the pilot development stage. Markers are monodisperse polymer spheres containing their uniqu
{"title":"Practical Application of the Fluorescent Microspheres Method Technology in Horizontal Wells of the Upper Salym Oil Field: Efficiency of the Method, Technology and Approach","authors":"Ya.G. Gorbachev, D. Chaplygin, D. Khamadaliev, Viktor Yashnev, Igor Novikov, K. Ovchinnikov, A. Katashov, E. Malyavko, K. Saprykina, Vasily Kiselev","doi":"10.2118/196835-ms","DOIUrl":"https://doi.org/10.2118/196835-ms","url":null,"abstract":"\u0000 The development of hydraulic fracturing technology began with single operations and is currently the most effective tool for increasing the productivity of wells and managing field development. Without the application of the hydraulic fracturing method, many fields would not have been successfully put into operation. For example, in the USA, hydraulic fracturing technology is used almost everywhere, which enabled an increase in the share of recoverable reserves by 25-30%. The first hydraulic fracturing in our country was carried out in 1952. After this, the number of such works increased for several years, but then declined. This was due to the industrial development of large oil fields in Western Siberia. The application of hydraulic fracturing technology was resumed in the 1980s and has been growing steadily ever since (Usachev, 1986).\u0000 Horizontal drilling technologies are currently developing at a fairly rapid pace, which entails an increase in the accuracy of penetrating a given part of the formation. Multi-stage hydraulic fracturing is primarily used in the well to increase the flow rate. It is expected that in the perspective of 2019-2020, the share of horizontal drilling will reach 46-50%, which is due to plans for the intensive development of new fields in Eastern Siberia (Figure 1). Figure 1Dynamics of the number of wells completed using horizontal and controlled directional drilling in Russia in 2008–2026 (fact and forecast), units\u0000 There has been a steady increase in the share of horizontal drilling with the total volume of production in Russia since 2008 (Figure 2). This indicates qualitative changes in the technological approaches of today's production companies. Figure 2Dynamics of throughput volume in production drilling in Russia in 2008–2026 (fact and forecast), mln. m.\u0000 Technical solutions are required for the delivery of geophysical equipment to the horizontal section of the well for horizontal wells production logging using an electric centrifugal pump (ESP). The existing Y-tool technology allows for lowering the geophysical equipment to the coiled tubing system, therefore bypassing the ESP system in close proximity to well operation mode, but this increases the well completion cost by 25%.\u0000 Along with the conventional methods of horizontal wells production logging such as PLT logging, oil producing companies are increasingly beginning to apply innovative methods based on marker technology. This method applies the flow indicators that are able to trace the flow of each phase into the well separately and continuously for several years. The objective of this article is to describe the results of using the fluorescent microsphere method, taking into account their long-term use for estimating the inflow structure from each port of hydraulic fracturing in horizontal wells. This helps users to avoid risky and costly downhole operations at the pilot development stage.\u0000 Markers are monodisperse polymer spheres containing their uniqu","PeriodicalId":10977,"journal":{"name":"Day 2 Wed, October 23, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-10-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"72802444","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}
I. Bazyrov, R. R. Galeev, A. Ipatov, Ilya Kayeshkov, S. Simakov, I. Fayzullin, E. Shel, Aleksandr Sheremeev, A. Shurunov, A. Yakovlev, M. Bikkulov, Ruslan Gayaztdinov, R. Uchuev, A. Logvinyuk
At the pilot area of the oilfield in the Khanty-Mansi Autonomous Okrug, pilot works are being carried out to increase the development efficiency of low-permeability reservoirs using horizontal production and injection wells with transverse multistage hydraulic fractures (A.Shurunov et al., 2018). The paper describes the results of one stage of pilot works – the shifting of the central horizontal well into the injection and equipping this well with a fiber-optic system (FOS) for monitoring the downhole temperature field (DTS) and vibroacoustic oscillations (DAS). This work is a continuation of the work (A.Shurunov et al., 2018) and (R.Galeev et al., 2018) in the field of development of delivery methods for FOS in multiple-fractured horizontal wells (MFHW), testing the technology of DTS and DAS to evaluate the effectiveness of waterflooding of low-permeability reservoirs and monitoring the propagation of waterflood-induced fractures in injection horizontal well with transverse multistage hydraulic fractures.
{"title":"Dynamic Control of the Efficiency of Waterflooding of Low-Permeability Reservoirs by Horizontal Injection Wells With Transverse Multi-Stage Hydraulic Fractures","authors":"I. Bazyrov, R. R. Galeev, A. Ipatov, Ilya Kayeshkov, S. Simakov, I. Fayzullin, E. Shel, Aleksandr Sheremeev, A. Shurunov, A. Yakovlev, M. Bikkulov, Ruslan Gayaztdinov, R. Uchuev, A. Logvinyuk","doi":"10.2118/196739-ms","DOIUrl":"https://doi.org/10.2118/196739-ms","url":null,"abstract":"\u0000 At the pilot area of the oilfield in the Khanty-Mansi Autonomous Okrug, pilot works are being carried out to increase the development efficiency of low-permeability reservoirs using horizontal production and injection wells with transverse multistage hydraulic fractures (A.Shurunov et al., 2018). The paper describes the results of one stage of pilot works – the shifting of the central horizontal well into the injection and equipping this well with a fiber-optic system (FOS) for monitoring the downhole temperature field (DTS) and vibroacoustic oscillations (DAS).\u0000 This work is a continuation of the work (A.Shurunov et al., 2018) and (R.Galeev et al., 2018) in the field of development of delivery methods for FOS in multiple-fractured horizontal wells (MFHW), testing the technology of DTS and DAS to evaluate the effectiveness of waterflooding of low-permeability reservoirs and monitoring the propagation of waterflood-induced fractures in injection horizontal well with transverse multistage hydraulic fractures.","PeriodicalId":10977,"journal":{"name":"Day 2 Wed, October 23, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-10-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80835646","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}
It is the purpose of this paper to search for options to improve technical and economic efficiency of hydraulic fracturing. The paper presents conventional hydraulic fracturing technologies at multiple development targets and interval frac technology using diverter soluble balls for directional wells under the conditions of multiple development targets. The paper also presents experience of technology application at the enterprise and economic analysis (costs reduction for workover actions). The technology is based on application of diverter soluble balls and it allows performing selective hydraulic fracturing for two and more productive formations for one packer trip-in and one frac fleet approach thereby enabling considerable reduction in the time and increasing the economic value of actions. The main elements of the process are diverter balls which plug (creating a temporary artificial overlap) perforated intervals of the first development target after fracturing at a continuous process, enabling flow redistribution and deviation of frac drive fluid to lesser permeable second frac development target. The process is continuous as follows DFIT, frac #1, diverter balls injection, frac #2. Diverter balls have been tested in the enterprise’s labs against characteristics and properties, compatibility of products with formation fluids. Frac technology using diverter balls has been successfully tested as part of the pilot project and it is applied at the enterprise on a commercial scale enabling reduce costs for workover crew’s work by 23%, workover actions – by 20%, increasing profitability of frac workover actions for both an existing producing well stock and at the cost of a new well stock drilling. It is worthwhile noting that the existing conventional frac equipment allows applying the technology. It does not need special upgrading. The technology applicability criteria are identified. Success of works which have already been performed is over 95% and it is approved by well logging to determine flow profile. The technology application allows involving into development all low productive formations of dissected section with a considerable reduction in the time and workover action costs.
{"title":"Increase in Profitability Ratio of Hydraulic Fracturing for Multi-Layer Formation","authors":"Ruslan R. Mardamshin","doi":"10.2118/196988-ms","DOIUrl":"https://doi.org/10.2118/196988-ms","url":null,"abstract":"\u0000 It is the purpose of this paper to search for options to improve technical and economic efficiency of hydraulic fracturing. The paper presents conventional hydraulic fracturing technologies at multiple development targets and interval frac technology using diverter soluble balls for directional wells under the conditions of multiple development targets. The paper also presents experience of technology application at the enterprise and economic analysis (costs reduction for workover actions).\u0000 The technology is based on application of diverter soluble balls and it allows performing selective hydraulic fracturing for two and more productive formations for one packer trip-in and one frac fleet approach thereby enabling considerable reduction in the time and increasing the economic value of actions. The main elements of the process are diverter balls which plug (creating a temporary artificial overlap) perforated intervals of the first development target after fracturing at a continuous process, enabling flow redistribution and deviation of frac drive fluid to lesser permeable second frac development target. The process is continuous as follows DFIT, frac #1, diverter balls injection, frac #2.\u0000 Diverter balls have been tested in the enterprise’s labs against characteristics and properties, compatibility of products with formation fluids. Frac technology using diverter balls has been successfully tested as part of the pilot project and it is applied at the enterprise on a commercial scale enabling reduce costs for workover crew’s work by 23%, workover actions – by 20%, increasing profitability of frac workover actions for both an existing producing well stock and at the cost of a new well stock drilling. It is worthwhile noting that the existing conventional frac equipment allows applying the technology. It does not need special upgrading. The technology applicability criteria are identified. Success of works which have already been performed is over 95% and it is approved by well logging to determine flow profile. The technology application allows involving into development all low productive formations of dissected section with a considerable reduction in the time and workover action costs.","PeriodicalId":10977,"journal":{"name":"Day 2 Wed, October 23, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-10-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89219260","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. Zatsepin, F. Gubaidullin, A. Ushakova, S. Miftakhov
The considered "Super Fluid Water" (SFW) is developed aqueous solution of polyelectrolytes with extra low concentration. The aim of the present work is laboratory investigations and field studies of the water with reagent flow in porous media. Change in hydrodynamics of water flow – the mobility increase was observed for the SFW additives. Filtration studies of changes in the value of the residual resistance factor for core samples with different permeability were carried out. The conducting field tests were held using standard techniques and methods of field geological and geophysical studies. Temperature and profile logging were performed at different flow rates, with water and water with SFW injection (SWF concentration up to 1%). Laboratory studies have shown that the value of the residual resistance factor is lower than the value of the absolute permeability of the core sample, and the dependence is approximated by the power function. The established laboratory dependence confirmed the possibility of using the SFW reagent for conformance control in injection wells, which determined the goals and objectives of field studies. The field studies were performed (we provide the information about the success treatments of 4 injection wells, no information about the unsuccessful treatments) and showed that the use of the reagent SFW leads to a dramatic increase of the injection capacity of the wells (210% and more). Estimation of the injection capacity profile before and after the use of SFW reagent showed the extension of operating intervals by including of extra low permeable layers (less than 1-2 mD) not previously drained by water. At the same time, the efficiency of SFW technology in these conditions is estimated to be higher than the technologies associated with gas injection into the reservoir. The achieved results allow us to assert the prospects of using SFW technology for the development of low-permeable reservoirs. The employment of this technology in the practice of oil recovery engineering will increase the efficiency of field development and oil recovery by 15-20%.
{"title":"Development of Low-Permeability Reservoirs by Increasing the Mobility of Water in a Porous Medium Using a Chemical Reagent - Super Fluid Water SFW","authors":"V. Zatsepin, F. Gubaidullin, A. Ushakova, S. Miftakhov","doi":"10.2118/196779-ms","DOIUrl":"https://doi.org/10.2118/196779-ms","url":null,"abstract":"\u0000 The considered \"Super Fluid Water\" (SFW) is developed aqueous solution of polyelectrolytes with extra low concentration. The aim of the present work is laboratory investigations and field studies of the water with reagent flow in porous media. Change in hydrodynamics of water flow – the mobility increase was observed for the SFW additives.\u0000 Filtration studies of changes in the value of the residual resistance factor for core samples with different permeability were carried out. The conducting field tests were held using standard techniques and methods of field geological and geophysical studies. Temperature and profile logging were performed at different flow rates, with water and water with SFW injection (SWF concentration up to 1%).\u0000 Laboratory studies have shown that the value of the residual resistance factor is lower than the value of the absolute permeability of the core sample, and the dependence is approximated by the power function. The established laboratory dependence confirmed the possibility of using the SFW reagent for conformance control in injection wells, which determined the goals and objectives of field studies.\u0000 The field studies were performed (we provide the information about the success treatments of 4 injection wells, no information about the unsuccessful treatments) and showed that the use of the reagent SFW leads to a dramatic increase of the injection capacity of the wells (210% and more).\u0000 Estimation of the injection capacity profile before and after the use of SFW reagent showed the extension of operating intervals by including of extra low permeable layers (less than 1-2 mD) not previously drained by water.\u0000 At the same time, the efficiency of SFW technology in these conditions is estimated to be higher than the technologies associated with gas injection into the reservoir.\u0000 The achieved results allow us to assert the prospects of using SFW technology for the development of low-permeable reservoirs. The employment of this technology in the practice of oil recovery engineering will increase the efficiency of field development and oil recovery by 15-20%.","PeriodicalId":10977,"journal":{"name":"Day 2 Wed, October 23, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-10-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83548977","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. Karpov, N. Parshin, A. Ryazanov, K. Ovchinnikov, Igor Novikov, E. Malyavko
In today’s operations in the conditions of drilling technologies active development, well completion and production intensification, there is a tendency towards increasing growth lengths of horizontal sections of horizontal drilling volumes, resulting in an increase of multi-zone hydraulic fracturing stages. With existing conventional horizontal well logging methods, alternative technologies that utilize tracer-based inflow indicators are becoming more common. These technologies enable horizontal well production logging and allow users to obtain long-term analytical information. The objective of this article is to analyze the efficiency of several production logging methods applied to horizontal wells with multi-stage hydraulic fracturing at Sredne-Nazymskoye field. During the project, horizontal well oil and water inflows were monitored using a 15-stage hydraulic fracturing and the application of marked polymer-coated proppant. Monodisperse polymer microglobules, encoded for each stage of the multi-stage hydraulic fracturing and interacting selectively with water and oil, were used as markers. Upon completion of the stimulation works and once the well was put into operation, formation fluid sampling from the wellhead was carried out with subsequent analysis to determine the concentration of markers of each code and was associated with fracturing stages. Well production logging with the marked proppant application was carried out periodically for several months, and the horizontal well profiles were built on the basis of the obtained analytical data. The results allowed us to conduct a long-term analysis of the stimulation efficiency for each of the hydraulic fracturing stages. We also used the data to assess the formation reserves development for each of the multi-stage hydraulic fracturing stages. In contrast to conventional logging methods, the primary advantage of the horizontal well production logging technology is that there is no requirement to use special means of tool deliver and there is no risk of down-hole tools getting stuck or a loss or ambiguity of interpretation. During the course of the study, the performance of the monitoring technology was confirmed using flow indicators placed in the hydraulic fractures, providing long-term selective interaction of marker particles with water and oil parts of formation fluid. The obtained geological and technical information contributes to further planning of effective geological and technical measures and additional oil recovery.
{"title":"Experience of Using Various Horizontal Well Logging Technologies During Multi-Stage Hydraulic Fracturing at Sredne-Nazymskoye Field","authors":"V. Karpov, N. Parshin, A. Ryazanov, K. Ovchinnikov, Igor Novikov, E. Malyavko","doi":"10.2118/196965-ms","DOIUrl":"https://doi.org/10.2118/196965-ms","url":null,"abstract":"\u0000 In today’s operations in the conditions of drilling technologies active development, well completion and production intensification, there is a tendency towards increasing growth lengths of horizontal sections of horizontal drilling volumes, resulting in an increase of multi-zone hydraulic fracturing stages.\u0000 With existing conventional horizontal well logging methods, alternative technologies that utilize tracer-based inflow indicators are becoming more common. These technologies enable horizontal well production logging and allow users to obtain long-term analytical information.\u0000 The objective of this article is to analyze the efficiency of several production logging methods applied to horizontal wells with multi-stage hydraulic fracturing at Sredne-Nazymskoye field.\u0000 During the project, horizontal well oil and water inflows were monitored using a 15-stage hydraulic fracturing and the application of marked polymer-coated proppant. Monodisperse polymer microglobules, encoded for each stage of the multi-stage hydraulic fracturing and interacting selectively with water and oil, were used as markers. Upon completion of the stimulation works and once the well was put into operation, formation fluid sampling from the wellhead was carried out with subsequent analysis to determine the concentration of markers of each code and was associated with fracturing stages.\u0000 Well production logging with the marked proppant application was carried out periodically for several months, and the horizontal well profiles were built on the basis of the obtained analytical data. The results allowed us to conduct a long-term analysis of the stimulation efficiency for each of the hydraulic fracturing stages. We also used the data to assess the formation reserves development for each of the multi-stage hydraulic fracturing stages.\u0000 In contrast to conventional logging methods, the primary advantage of the horizontal well production logging technology is that there is no requirement to use special means of tool deliver and there is no risk of down-hole tools getting stuck or a loss or ambiguity of interpretation.\u0000 During the course of the study, the performance of the monitoring technology was confirmed using flow indicators placed in the hydraulic fractures, providing long-term selective interaction of marker particles with water and oil parts of formation fluid. The obtained geological and technical information contributes to further planning of effective geological and technical measures and additional oil recovery.","PeriodicalId":10977,"journal":{"name":"Day 2 Wed, October 23, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-10-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85397960","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. Zubarev, R. Mardanov, Vitaly A. Bochkarev, Vyacheslav Khmelevskij
Interference testing is a common tool for addressing reservoir connectivity and compartmentalization risks. Due to the high costs of deep-water and ultra-deep-water extended well testing, this type of test is rarely performed during the appraisal phase and is usually postponed until the start of the field development. With the infrastructure in place, testing can be carried out with minimum planning and at a minimum cost. This is generally acceptable for fields with a lower subsurface complexity. However, for complex turbidite fields, this information becomes critical at the appraisal and early development planning stages to reduce the risks in depletion optimization and production infrastructure planning. To make testing practical, it has to be performed in a way that minimizes rig time and de-risks collection of required data. To optimize the interference test design for the West Africa deep-water field appraisal phase, a simulation study was carried out to assess the impact of major uncertainties. A fine-scale 3D simulation model was used due to high heterogeneity and complex connectivity between individual channels and channel complexes. Impact of the drawdown rate, flow duration, tidal effect amplitude, OWC, faults transmissibility, absolute permeability, reservoir pore volume, and zones connectivity on interference time for different selections of test and observation wells were assessed through the sensitivity runs. Results were analyzed to get a better understanding of reservoir dynamic response such as pressure travel time and potential interference between zones. Based on this study a flexible interference test plan was defined that ensures optimal rig use and minimal risk of sub-optimal dataset collection. This plan embeds both pre-test decisions and real-time decisions that depend on early time observations. An optimal test and observation wells setup that provides a balance between the rig time and value of information will depend on the planned appraisal well results and is one of the decisions to be finalized before the test. However, decisions on flow duration adjustment and consequent data monitoring in the observation wells will be made based on a set of early time events identified from the sensitivity of pressure interference response between different zones and wells. The proposed uncertainty driven approach provides an obvious advantage over the common test design based on the "best technical estimate" model. It also provides a better basis for test feasibility decision and cost-effective implementation.
{"title":"Flexible Multi-Well Interference Test Design for a Deep-Water Field","authors":"D. Zubarev, R. Mardanov, Vitaly A. Bochkarev, Vyacheslav Khmelevskij","doi":"10.2118/196837-ms","DOIUrl":"https://doi.org/10.2118/196837-ms","url":null,"abstract":"\u0000 Interference testing is a common tool for addressing reservoir connectivity and compartmentalization risks. Due to the high costs of deep-water and ultra-deep-water extended well testing, this type of test is rarely performed during the appraisal phase and is usually postponed until the start of the field development. With the infrastructure in place, testing can be carried out with minimum planning and at a minimum cost. This is generally acceptable for fields with a lower subsurface complexity. However, for complex turbidite fields, this information becomes critical at the appraisal and early development planning stages to reduce the risks in depletion optimization and production infrastructure planning. To make testing practical, it has to be performed in a way that minimizes rig time and de-risks collection of required data.\u0000 To optimize the interference test design for the West Africa deep-water field appraisal phase, a simulation study was carried out to assess the impact of major uncertainties. A fine-scale 3D simulation model was used due to high heterogeneity and complex connectivity between individual channels and channel complexes. Impact of the drawdown rate, flow duration, tidal effect amplitude, OWC, faults transmissibility, absolute permeability, reservoir pore volume, and zones connectivity on interference time for different selections of test and observation wells were assessed through the sensitivity runs. Results were analyzed to get a better understanding of reservoir dynamic response such as pressure travel time and potential interference between zones.\u0000 Based on this study a flexible interference test plan was defined that ensures optimal rig use and minimal risk of sub-optimal dataset collection. This plan embeds both pre-test decisions and real-time decisions that depend on early time observations. An optimal test and observation wells setup that provides a balance between the rig time and value of information will depend on the planned appraisal well results and is one of the decisions to be finalized before the test. However, decisions on flow duration adjustment and consequent data monitoring in the observation wells will be made based on a set of early time events identified from the sensitivity of pressure interference response between different zones and wells.\u0000 The proposed uncertainty driven approach provides an obvious advantage over the common test design based on the \"best technical estimate\" model. It also provides a better basis for test feasibility decision and cost-effective implementation.","PeriodicalId":10977,"journal":{"name":"Day 2 Wed, October 23, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-10-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81835864","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. Solovyev, Dzheykhun Soltanov, Artem Galimzyanov, Konstantin Naydenskiy, M. Nukhaev, I. Mukhametshin
Most of the new oil fields in Western Siberia have unfavorable conditions for field development such as excessive gas cap presents, oil rims and active water aquifer. The North-Komsomolskoe oilfield is also characterized by poor consolidated sandstone and high viscous oil. Different types of reservoir completion (ICD, ACID, AICV) have been decided to trial test for this field in order to mitigate early water or gas breakthrough along the long horizontal well. During this trial testing of the optimum type of lower completion, the continuous well monitoring is required; clean-up efficiency estimation after drilling, quantitative estimation of inflow per compartment along the wellbore and localization of water or gas breakthrough. Traditional well logging methods like production logging cannot always be easily applied technically and be cost-effective for many surveys during well life. This article presents the result of using a novel technology based on chemical tracer for continuous well monitoring. Polymer matrix with chemical markers for oil and water have been integrated into different types of lower completion (ICD, AICD, Stand Along Screen) and run into the hole as a part of liner string. Technology of intelligent chemical tracers is used to monitor well performance over a long period of well life, which allows to obtain the following information: effectiveness of clean up operation after drilling, inflow per compartment and water/gas breakthrough localization zone. To confirm interpretation results based on chemical tracer, the traditional method (production logging) was used to measure inflow along the wellbore and compare with result from tracer survey.
{"title":"Successful Application of the Intelligent Inflow Tracers for Monitoring of Horizontal Wells on North Komsomolskoe Field","authors":"T. Solovyev, Dzheykhun Soltanov, Artem Galimzyanov, Konstantin Naydenskiy, M. Nukhaev, I. Mukhametshin","doi":"10.2118/196831-ms","DOIUrl":"https://doi.org/10.2118/196831-ms","url":null,"abstract":"\u0000 Most of the new oil fields in Western Siberia have unfavorable conditions for field development such as excessive gas cap presents, oil rims and active water aquifer. The North-Komsomolskoe oilfield is also characterized by poor consolidated sandstone and high viscous oil. Different types of reservoir completion (ICD, ACID, AICV) have been decided to trial test for this field in order to mitigate early water or gas breakthrough along the long horizontal well. During this trial testing of the optimum type of lower completion, the continuous well monitoring is required; clean-up efficiency estimation after drilling, quantitative estimation of inflow per compartment along the wellbore and localization of water or gas breakthrough. Traditional well logging methods like production logging cannot always be easily applied technically and be cost-effective for many surveys during well life. This article presents the result of using a novel technology based on chemical tracer for continuous well monitoring.\u0000 Polymer matrix with chemical markers for oil and water have been integrated into different types of lower completion (ICD, AICD, Stand Along Screen) and run into the hole as a part of liner string. Technology of intelligent chemical tracers is used to monitor well performance over a long period of well life, which allows to obtain the following information: effectiveness of clean up operation after drilling, inflow per compartment and water/gas breakthrough localization zone. To confirm interpretation results based on chemical tracer, the traditional method (production logging) was used to measure inflow along the wellbore and compare with result from tracer survey.","PeriodicalId":10977,"journal":{"name":"Day 2 Wed, October 23, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-10-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88046917","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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