R. Urazov, A. Davletbaev, A. I. Sinitskiy, I. Zarafutdinov, Artur Khamitovich Nuriev, V. Sarapulova, Oxana Evgenievna Nosova
This research presents a modified approach to the data interpretation of Rate Transient Analysis (RTA) in hydraulically fractured horizontal well. The results of testing of data interpretation technique taking account of the flow allocation in the borehole according to the well logging and to the injection tests outcomes while carrying out hydraulic fracturing are given. In the course of the interpretation of the field data the parameters of each fracture of hydraulic fracturing were selected with control for results of well logging (WL) by defining the fluid influx in the borehole.
{"title":"The Interpretation Technique of Rate Transient Analysis Data in Fractured Horizontal Wells","authors":"R. Urazov, A. Davletbaev, A. I. Sinitskiy, I. Zarafutdinov, Artur Khamitovich Nuriev, V. Sarapulova, Oxana Evgenievna Nosova","doi":"10.2118/206484-ms","DOIUrl":"https://doi.org/10.2118/206484-ms","url":null,"abstract":"\u0000 This research presents a modified approach to the data interpretation of Rate Transient Analysis (RTA) in hydraulically fractured horizontal well. The results of testing of data interpretation technique taking account of the flow allocation in the borehole according to the well logging and to the injection tests outcomes while carrying out hydraulic fracturing are given. In the course of the interpretation of the field data the parameters of each fracture of hydraulic fracturing were selected with control for results of well logging (WL) by defining the fluid influx in the borehole.","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"413 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76447567","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}
Konstantin Yurievich Loskutov, A. A. Sadretdinov, Michael Ivanovich Samoilov, D. Emelyanov, Yuri Aleksandrovich Delyanov, Svetlana Rafailievna Pavlova
Tyumenskaya and Vikulovskya stratas are the major development objects for Rosneft subsidiary – RN- Nyaganneftegaz, characterized by close location of target zones to other layers, breakthrough in which is not desirable. Thus, target zones of Tyumenskaya group of formations are located close to Abalakskaya strata, and Vikulovskaya group of formations is described by close location of the target hydraulic fracturing intervals to the water-saturated layers. Risks of multi-stage hydraulic fracturing are high due to the use of synthetic geological and geomechanical models and synthetic logging associated with different sections of horizontal wells. The article presents the implementation experience of specifically developed technological solution in order to increase profitability of development and production of hydrocarbons and decrease the risks of ineffective stimulation: use of low-viscosity viscoelastic hydraulic fracturing fluids based on synthetic polymer- polyacrylamide with inherited ability to control fracture height growth without a need in significant reduction of proppant volume. The work performed on development and introduction of novel low-viscosity fluids based on polyacrylamide on Vikulovskaya and Tyumenskaya formations - RN-Nyaganneftegaz development objects has become a new stage in the history of hydraulic fracturing of these formations, and as well as for other oilfields with similar geological structure and field development conditions. The gained experience formed a basis for the effective implementation of similar hydraulic fracturing fluid systems and increasing of well productivity following in the result of well stimulation.
{"title":"Fracturing Experience of Tyumenskaya and Vikulovskaya Formations: Application of Novel Low-Viscosity Fracturing Fluids as an Alternative to Guar-Based Fluids","authors":"Konstantin Yurievich Loskutov, A. A. Sadretdinov, Michael Ivanovich Samoilov, D. Emelyanov, Yuri Aleksandrovich Delyanov, Svetlana Rafailievna Pavlova","doi":"10.2118/206644-ms","DOIUrl":"https://doi.org/10.2118/206644-ms","url":null,"abstract":"\u0000 Tyumenskaya and Vikulovskya stratas are the major development objects for Rosneft subsidiary – RN- Nyaganneftegaz, characterized by close location of target zones to other layers, breakthrough in which is not desirable.\u0000 Thus, target zones of Tyumenskaya group of formations are located close to Abalakskaya strata, and Vikulovskaya group of formations is described by close location of the target hydraulic fracturing intervals to the water-saturated layers. Risks of multi-stage hydraulic fracturing are high due to the use of synthetic geological and geomechanical models and synthetic logging associated with different sections of horizontal wells.\u0000 The article presents the implementation experience of specifically developed technological solution in order to increase profitability of development and production of hydrocarbons and decrease the risks of ineffective stimulation: use of low-viscosity viscoelastic hydraulic fracturing fluids based on synthetic polymer- polyacrylamide with inherited ability to control fracture height growth without a need in significant reduction of proppant volume.\u0000 The work performed on development and introduction of novel low-viscosity fluids based on polyacrylamide on Vikulovskaya and Tyumenskaya formations - RN-Nyaganneftegaz development objects has become a new stage in the history of hydraulic fracturing of these formations, and as well as for other oilfields with similar geological structure and field development conditions. The gained experience formed a basis for the effective implementation of similar hydraulic fracturing fluid systems and increasing of well productivity following in the result of well stimulation.","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"26 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77325568","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}
Pavel Dmitrievich Gladkov, Anastasiia Vladimirovna Zheltikova
As is known, fractured reservoirs compared to conventional reservoirs have such features as complex pore volume structure, high heterogeneity of the porosity and permeability properties etc. Apart from this, the productivity of a specific well is defined above all by the number of natural fractures penetrated by the wellbore and their properties. Development of fractured reservoirs is associated with a number of issues, one of which is related to uneven and accelerated water flooding due to water breakthrough through fractures to the wellbores, for this reason it becomes difficult to forecast the well performance. Under conditions of lack of information on the reservoir structure and aquifer activity, the 3D digital models of the field generated using the hydrodynamic simulators may feature insufficient predictive capability. However, forecasting of breakthroughs is important in terms of generating reliable HC and water production profiles and decision-making on reservoir management and field facilities for produced water treatment. Identification of possible sources of water flooding and planning of individual parameters of production well operation for the purpose of extending the water-free operation period play significant role in the development of these reservoirs. The purpose of this study is to describe the results of the hydrochemical monitoring to forecast the water flooding of the wells that penetrated a fractured reservoir on the example of a gas condensate field in Bolivia. The study contains data on the field development status and associated difficulties and uncertainties. The initial data were results of monthly analyses of the produced water and the water-gas ratio dynamics that were analyzed and compared to the data on the analogue fields. The data analysis demonstrated that first signs of water flooding for the wells of the field under study may be diagnosed through the monitoring of the produced water mineralization - the water-gas ratio (WGR) increase is preceded by the mineralization increase that may be observed approximately a month earlier. However, the data on the analogue fields shows that this period may be longer – from few months to two years. Thus, the hydrochemical method within integrated monitoring of development of a field with a fractured reservoir could be one of the efficient methods to timely adjust the well operation parameters and may extend the water-free period of its operation.
{"title":"Forecasting the Water Flooding for the Production Wells of a Gas Condensate Field with a Fractured Reservoir Type","authors":"Pavel Dmitrievich Gladkov, Anastasiia Vladimirovna Zheltikova","doi":"10.2118/206578-ms","DOIUrl":"https://doi.org/10.2118/206578-ms","url":null,"abstract":"\u0000 As is known, fractured reservoirs compared to conventional reservoirs have such features as complex pore volume structure, high heterogeneity of the porosity and permeability properties etc. Apart from this, the productivity of a specific well is defined above all by the number of natural fractures penetrated by the wellbore and their properties. Development of fractured reservoirs is associated with a number of issues, one of which is related to uneven and accelerated water flooding due to water breakthrough through fractures to the wellbores, for this reason it becomes difficult to forecast the well performance.\u0000 Under conditions of lack of information on the reservoir structure and aquifer activity, the 3D digital models of the field generated using the hydrodynamic simulators may feature insufficient predictive capability. However, forecasting of breakthroughs is important in terms of generating reliable HC and water production profiles and decision-making on reservoir management and field facilities for produced water treatment. Identification of possible sources of water flooding and planning of individual parameters of production well operation for the purpose of extending the water-free operation period play significant role in the development of these reservoirs.\u0000 The purpose of this study is to describe the results of the hydrochemical monitoring to forecast the water flooding of the wells that penetrated a fractured reservoir on the example of a gas condensate field in Bolivia. The study contains data on the field development status and associated difficulties and uncertainties. The initial data were results of monthly analyses of the produced water and the water-gas ratio dynamics that were analyzed and compared to the data on the analogue fields. The data analysis demonstrated that first signs of water flooding for the wells of the field under study may be diagnosed through the monitoring of the produced water mineralization - the water-gas ratio (WGR) increase is preceded by the mineralization increase that may be observed approximately a month earlier. However, the data on the analogue fields shows that this period may be longer – from few months to two years.\u0000 Thus, the hydrochemical method within integrated monitoring of development of a field with a fractured reservoir could be one of the efficient methods to timely adjust the well operation parameters and may extend the water-free period of its operation.","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"274 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85685490","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. Pletneva, D. Korobkov, A. Kornilov, I. Safonov, I. Yakimchuk, M. Stukan
Interfacial tension (IFT) is one of the key parameters governing multiphase flow in reservoir. One of standard IFT measurement techniques is pendant drop shape analysis, which includes an acquisition of the drop snapshots in visible light. Hence, the method is limited by optical transparency of an external fluid. Here we present a new approach, which is free from this limitation. It uses X-rays as an illumination source and provides a number of advantages and additional opportunities in the study of fluid interface behavior. Proposed method includes a drop generation inside a uniquely designed X-ray transparent cell for high pressure and temperature (HPHT) measurements placed inside an X-ray scanner and imaging of its evolution with time till equilibrium state. Since X-ray images significantly differ from the classical optical ones, a novel algorithm was developed for accurate drop shape detection and further mathematical processing for IFT value calculation. As a result, an IFT value evolution curve for a pair of fluids is obtained. Depending on relative densities of the fluids, different experimental schemes can be implemented: pendant or rising drop. The method was validated on various neat fluids with well-known IFT values and then was successfully applied for different real fluids systems. This work demonstrates the unique laboratory studies carried out on different liquid-fluid systems showing that the developed methodology works well at elevated pressure and temperature conditions. The developed method unlocks the possibility for an appropriate IFT measurements in surfactant-rich oil-water systems as well as in systems near the phase transition such as gas-condensates at a wide range of thermobaric reservoir conditions and increases feasibility of HPHT measurements due to simplification of the measuring system design.
{"title":"Interfacial Tension Measurements at Reservoir Conditions Using X-Ray Imaging","authors":"V. Pletneva, D. Korobkov, A. Kornilov, I. Safonov, I. Yakimchuk, M. Stukan","doi":"10.2118/206480-ms","DOIUrl":"https://doi.org/10.2118/206480-ms","url":null,"abstract":"\u0000 Interfacial tension (IFT) is one of the key parameters governing multiphase flow in reservoir. One of standard IFT measurement techniques is pendant drop shape analysis, which includes an acquisition of the drop snapshots in visible light. Hence, the method is limited by optical transparency of an external fluid. Here we present a new approach, which is free from this limitation. It uses X-rays as an illumination source and provides a number of advantages and additional opportunities in the study of fluid interface behavior. Proposed method includes a drop generation inside a uniquely designed X-ray transparent cell for high pressure and temperature (HPHT) measurements placed inside an X-ray scanner and imaging of its evolution with time till equilibrium state. Since X-ray images significantly differ from the classical optical ones, a novel algorithm was developed for accurate drop shape detection and further mathematical processing for IFT value calculation. As a result, an IFT value evolution curve for a pair of fluids is obtained. Depending on relative densities of the fluids, different experimental schemes can be implemented: pendant or rising drop.\u0000 The method was validated on various neat fluids with well-known IFT values and then was successfully applied for different real fluids systems. This work demonstrates the unique laboratory studies carried out on different liquid-fluid systems showing that the developed methodology works well at elevated pressure and temperature conditions.\u0000 The developed method unlocks the possibility for an appropriate IFT measurements in surfactant-rich oil-water systems as well as in systems near the phase transition such as gas-condensates at a wide range of thermobaric reservoir conditions and increases feasibility of HPHT measurements due to simplification of the measuring system design.","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"13 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88645223","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}
Ivan Lebedev, A. Gabdullin, Oleg Vasilievich Korepin, Sergey Stanislavivich Dubitskit, Sergey Vladimirovich Novikiv, Sergey Victorovich Feklenkov
The resource base of the north of the West Siberian oil and gas province is the basis of Russia's energy strategy. Among the northern territories of the province, the Nadym-Purskaya, Pur-Tazovskaya and Yamal oil and gas regions (OGRs) are the leaders in terms of estimated gas reserves (Figure 1). However, the largest deposits of the first two OGRs are in the stage of falling production. Therefore, the main prospects should be associated with the Yamal OGR, which has not yet been put into active operation. It is logical that along with the development of traditional methods of extraction of "dry" natural gas, the government of the Russian Federation has approved a plan for the production of liquefied natural gas based on the fields of the Yamal Peninsula, which is currently being actively implemented by PJSC "NOVATEK". (https://www.novatek.rU/m/business/exploration/)
{"title":"Construction of a Multipurpose Exploration Well in the Jurassic Deposits Subsequent Transfer to Production Enabled by Metal Expandable Barrier Installed Behind the Casing","authors":"Ivan Lebedev, A. Gabdullin, Oleg Vasilievich Korepin, Sergey Stanislavivich Dubitskit, Sergey Vladimirovich Novikiv, Sergey Victorovich Feklenkov","doi":"10.2118/206439-ms","DOIUrl":"https://doi.org/10.2118/206439-ms","url":null,"abstract":"\u0000 The resource base of the north of the West Siberian oil and gas province is the basis of Russia's energy strategy. Among the northern territories of the province, the Nadym-Purskaya, Pur-Tazovskaya and Yamal oil and gas regions (OGRs) are the leaders in terms of estimated gas reserves (Figure 1). However, the largest deposits of the first two OGRs are in the stage of falling production. Therefore, the main prospects should be associated with the Yamal OGR, which has not yet been put into active operation. It is logical that along with the development of traditional methods of extraction of \"dry\" natural gas, the government of the Russian Federation has approved a plan for the production of liquefied natural gas based on the fields of the Yamal Peninsula, which is currently being actively implemented by PJSC \"NOVATEK\". (https://www.novatek.rU/m/business/exploration/)","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"07 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81839252","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}
Askhat Radikovich Usmanov, Anton Mikhailovich Shishkin, A. Merzlyakov, J. Karimov, A. Fedotov, Vladimir Ivanovich Khlebnikov
Casing drilling technology, as an alternative to conventional drilling, has been known for a long time. This method is mainly used for wells with geological complications, such as lost circulation or wellbore instability of various nature. By using drilling on a string for a section or part of it, the problem interval is immediately cased, eliminating the time spent on additional operations, such as pulling the bottom hole assembly (BHA), wiper trips and running the casing. Thus, this allows to reduce the time for well construction, reduces the risk of accidents and non-productive time associated with the complication zone. Casing drilling has become widely for drilling vertical surface conductors and technical casing with a drillable shoe, as well as for drilling with retrievable BHA in inclined sections for 324- and 245-mm casing. The aim of this work was to perform directional drilling on a 178mm production casing in an interval where the client had geological problems associated with running casing due to a zone of rock collapse. The uniqueness of the task lies in the fact that no one in the world has yet performed drilling on a casing with a building inclination and landing into a horizontal plane. It was necessary to follow the designed well trajectory, to build inclination from 67 to 85 degrees with the planned dogleg severity of 1 degree / 10m.
{"title":"7-inch Casing While Drilling CWD With Retrievable Bottom Hole Assembly BHA","authors":"Askhat Radikovich Usmanov, Anton Mikhailovich Shishkin, A. Merzlyakov, J. Karimov, A. Fedotov, Vladimir Ivanovich Khlebnikov","doi":"10.2118/206438-ms","DOIUrl":"https://doi.org/10.2118/206438-ms","url":null,"abstract":"\u0000 Casing drilling technology, as an alternative to conventional drilling, has been known for a long time. This method is mainly used for wells with geological complications, such as lost circulation or wellbore instability of various nature. By using drilling on a string for a section or part of it, the problem interval is immediately cased, eliminating the time spent on additional operations, such as pulling the bottom hole assembly (BHA), wiper trips and running the casing. Thus, this allows to reduce the time for well construction, reduces the risk of accidents and non-productive time associated with the complication zone.\u0000 Casing drilling has become widely for drilling vertical surface conductors and technical casing with a drillable shoe, as well as for drilling with retrievable BHA in inclined sections for 324- and 245-mm casing.\u0000 The aim of this work was to perform directional drilling on a 178mm production casing in an interval where the client had geological problems associated with running casing due to a zone of rock collapse. The uniqueness of the task lies in the fact that no one in the world has yet performed drilling on a casing with a building inclination and landing into a horizontal plane. It was necessary to follow the designed well trajectory, to build inclination from 67 to 85 degrees with the planned dogleg severity of 1 degree / 10m.","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"2 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82984950","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}
Henadz Zaitsau, Valeri Shumilyak, Alexander Konyushenko
The main topic of an article is machine learning and classification (neural net) use for prognostic lithological model creation. Moreover, research preceding stages such as attribute analysis, seismic inversion, seismogeological modeling and briefly the results of lithological and petrophysical investigations are described in this art
{"title":"Generation of a Probabilistic Facial Model on the Basis of Lithology Logs, Well Logs, Seismic Data and Existing Methods of Machine Learning and Classification","authors":"Henadz Zaitsau, Valeri Shumilyak, Alexander Konyushenko","doi":"10.2118/206547-ms","DOIUrl":"https://doi.org/10.2118/206547-ms","url":null,"abstract":"\u0000 The main topic of an article is machine learning and classification (neural net) use for prognostic lithological model creation. Moreover, research preceding stages such as attribute analysis, seismic inversion, seismogeological modeling and briefly the results of lithological and petrophysical investigations are described in this art","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"17 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90721188","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, R. Farakhova, D. Gulyaev, Ramil Mingaraev, R. I. Khafizov
The main objective of the study is to compare the results of the cross-well tracers survey against the pulse code pressure interference testing (PCT) for the complicated geological structures. The study was based on the numerical simulations on the synthetic 3D models with popular geological complications, such as faults, vertical and horizontal reservoir anisotropy and pinch-outs. The study has set a special focus on quantitative analysis of the reservoir properties estimated by tracers and PCT as against the known values. This provides a text-book examples of advantages and disadvantages of both surveillance methods in different geological environment. Pulse code testing is specific implementation of pressure interference testing by creating a series of injection/production rate changes accordingly to a preset schedule to create a "pressure code" and monitoring the pressure response in the offset wells. The use of high-resolution quarts gauges is highly beneficial in case of large cross-well intervals scanning or poor reservoir quality in case of regular inter-well spacing. The tracer survey is based on injecting a liquid with chemical markers and subsequent capturing the markers at surface samples in the offset wells. The modern markers are relatively cheap and can be captured at very low concentrations thus making the cross-well scanning available even for high inter-well spacing. For synthetic models with vertical inhomogeneity the PCT provides a close estimate for compound dynamic reservoir properties (transmissibility and pressure diffusivity). For synthetic models with lateral inhomogeneity the PCT provides an accurate estimation for effective reservoir thickness and permeability. Tracers survey is not able to assess the reservoir thickness. The popular methods to assess reservoir permeability from tracers survey show a substantial deviation from the true reservoir permeability for synthetic models with vertical and lateral heterogeneity. This leads to conclusion that the most reliable application of racers survey is a qualitative assessment of cross-well connectivity and quantitative estimate of permeability in homogenous reservoirs. The first study of quantitative comparison of tracer survey against pressure pulse-code interference survey. Tracer survey and PCT efficiency was compared on 3D numerical models. Presence of synthetic models, describing geological complications, which may be seen very often on real reservoirs, provides a reliable basis for comparison.
{"title":"Comparative Analysis of Tracers Against Pressure Pulse Code Interference Testing based on the Numerical Simulations of the Synthetic Oilfields with Complicated Geology","authors":"A. Aslanyan, R. Farakhova, D. Gulyaev, Ramil Mingaraev, R. I. Khafizov","doi":"10.2118/206493-ms","DOIUrl":"https://doi.org/10.2118/206493-ms","url":null,"abstract":"\u0000 The main objective of the study is to compare the results of the cross-well tracers survey against the pulse code pressure interference testing (PCT) for the complicated geological structures.\u0000 The study was based on the numerical simulations on the synthetic 3D models with popular geological complications, such as faults, vertical and horizontal reservoir anisotropy and pinch-outs.\u0000 The study has set a special focus on quantitative analysis of the reservoir properties estimated by tracers and PCT as against the known values.\u0000 This provides a text-book examples of advantages and disadvantages of both surveillance methods in different geological environment.\u0000 Pulse code testing is specific implementation of pressure interference testing by creating a series of injection/production rate changes accordingly to a preset schedule to create a \"pressure code\" and monitoring the pressure response in the offset wells. The use of high-resolution quarts gauges is highly beneficial in case of large cross-well intervals scanning or poor reservoir quality in case of regular inter-well spacing.\u0000 The tracer survey is based on injecting a liquid with chemical markers and subsequent capturing the markers at surface samples in the offset wells. The modern markers are relatively cheap and can be captured at very low concentrations thus making the cross-well scanning available even for high inter-well spacing.\u0000 For synthetic models with vertical inhomogeneity the PCT provides a close estimate for compound dynamic reservoir properties (transmissibility and pressure diffusivity).\u0000 For synthetic models with lateral inhomogeneity the PCT provides an accurate estimation for effective reservoir thickness and permeability.\u0000 Tracers survey is not able to assess the reservoir thickness.\u0000 The popular methods to assess reservoir permeability from tracers survey show a substantial deviation from the true reservoir permeability for synthetic models with vertical and lateral heterogeneity.\u0000 This leads to conclusion that the most reliable application of racers survey is a qualitative assessment of cross-well connectivity and quantitative estimate of permeability in homogenous reservoirs.\u0000 The first study of quantitative comparison of tracer survey against pressure pulse-code interference survey. Tracer survey and PCT efficiency was compared on 3D numerical models. Presence of synthetic models, describing geological complications, which may be seen very often on real reservoirs, provides a reliable basis for comparison.","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"24 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75106296","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. Belyakov, D. Gulyaev, V. Krichevskiy, A. Nikonorova, Roman Edisonovich Iskibaev
The analyzed oi- gas field is based around Orenburg region, located 40 km away from the Buzuluk city, Russia. This multi-layered field has a number of domes. 11 productive layers lie within its cross-section. In total, 21 oil and two gas deposits have been identified at this field. The study layer A4 is confined to the top of the Bashkir layer and has a wide extension. Permeable rocks at this layer include limestone and dolomite, separated by impermeable sublayers. The effective oil-saturated well thicknesses vary between 1.1-38.4 m, and is 11.8 m on average. The caprock of the formation A4 consists of the Vereiskan clay-siltstone sequence.
{"title":"The Efficiency of the Novel Technology Reservoir Pressure Reconstruction Without Well Shut-in and without Production Losses","authors":"A. Belyakov, D. Gulyaev, V. Krichevskiy, A. Nikonorova, Roman Edisonovich Iskibaev","doi":"10.2118/206490-ms","DOIUrl":"https://doi.org/10.2118/206490-ms","url":null,"abstract":"\u0000 The analyzed oi- gas field is based around Orenburg region, located 40 km away from the Buzuluk city, Russia.\u0000 This multi-layered field has a number of domes. 11 productive layers lie within its cross-section. In total, 21 oil and two gas deposits have been identified at this field.\u0000 The study layer A4 is confined to the top of the Bashkir layer and has a wide extension. Permeable rocks at this layer include limestone and dolomite, separated by impermeable sublayers. The effective oil-saturated well thicknesses vary between 1.1-38.4 m, and is 11.8 m on average. The caprock of the formation A4 consists of the Vereiskan clay-siltstone sequence.","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"54 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85187641","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}
Yakov Dzhalatyan, M. Charupa, A. Galiev, Y. Karpekin, S. Egorov, A. Kishauov, Y. Smetanin, Alexey Pushkarskiy, Timur Arbatsky
In the presented paper, the object of the study are carbonate rocks of the Riphean and clastic-carbonate rocks of Vendian-Cambrian ages, uncovered by the well drilled at Yurubcheno-Tokhomskoye field. These reservoirs are characterized by extremely low porosity (1-4%) and determining saturation nature and fluid contacts cannot be reliably solved by conventional wireline petrophysical logging. Solutions to these problems are provided by interval testing using wireline formation evaluation testing tool (WFT). However, to obtain quality results from WFT testing it is important to identify porous intervals first by using advanced wireline logging services which are sensitive to porosity and fractures. In order to select the optimal WFT toolstring combination and to prospective testing intervals, advanced petrophysical wireline logging suit ran first. Porous reservoirs were identified from density, neutron and nuclear magnetic resonance evaluation. Saturation evaluated through dielectric and induction-based resistivity logging. In fracture-vug type reservoir, the main inflow of formation fluid into the well is provided from fractures, so it was very important to allocate conductive fractures to plan test intervals for WFT accordingly. based on imagers evaluation, fractures and faults were visualized; using Stoneley's wave conductive fractures, not clogged with drilling mud solids were identified; borehole acoustic reflection survey was used to segregate large fractures that propagated in the reservoir; During WFT logging, a total of 23 intervals were tested, for 8 of which reservoir fluid inflow was achieved, in all others, mainly with low porosity or single non-conductive fracture, the inflow was not achieved or was insignificant. According to the results of WFT testing, the nature of saturation for clastic-carbonate sediments of Vendian age was determined. Inflow of formation fluid (oil and water) from Riphean fractured reservoirs was achieved from 6 intervals, with identified fractures according to described above advanced logging suit. In addition, pressure transient analysis was performed, to measure the formation pressure, define pressure gradient curves and assess the fluids contact level with high confidence, for the first time for this field.
{"title":"Novel Integrated Approach for Complex Carbonate Reservoirs Testing with Wireline Formation Tester: Yurubcheno-Tokhomskoye Field Cases Study","authors":"Yakov Dzhalatyan, M. Charupa, A. Galiev, Y. Karpekin, S. Egorov, A. Kishauov, Y. Smetanin, Alexey Pushkarskiy, Timur Arbatsky","doi":"10.2118/206486-ms","DOIUrl":"https://doi.org/10.2118/206486-ms","url":null,"abstract":"\u0000 In the presented paper, the object of the study are carbonate rocks of the Riphean and clastic-carbonate rocks of Vendian-Cambrian ages, uncovered by the well drilled at Yurubcheno-Tokhomskoye field.\u0000 These reservoirs are characterized by extremely low porosity (1-4%) and determining saturation nature and fluid contacts cannot be reliably solved by conventional wireline petrophysical logging. Solutions to these problems are provided by interval testing using wireline formation evaluation testing tool (WFT). However, to obtain quality results from WFT testing it is important to identify porous intervals first by using advanced wireline logging services which are sensitive to porosity and fractures.\u0000 In order to select the optimal WFT toolstring combination and to prospective testing intervals, advanced petrophysical wireline logging suit ran first. Porous reservoirs were identified from density, neutron and nuclear magnetic resonance evaluation. Saturation evaluated through dielectric and induction-based resistivity logging.\u0000 In fracture-vug type reservoir, the main inflow of formation fluid into the well is provided from fractures, so it was very important to allocate conductive fractures to plan test intervals for WFT accordingly.\u0000 based on imagers evaluation, fractures and faults were visualized; using Stoneley's wave conductive fractures, not clogged with drilling mud solids were identified; borehole acoustic reflection survey was used to segregate large fractures that propagated in the reservoir;\u0000 During WFT logging, a total of 23 intervals were tested, for 8 of which reservoir fluid inflow was achieved, in all others, mainly with low porosity or single non-conductive fracture, the inflow was not achieved or was insignificant.\u0000 According to the results of WFT testing, the nature of saturation for clastic-carbonate sediments of Vendian age was determined. Inflow of formation fluid (oil and water) from Riphean fractured reservoirs was achieved from 6 intervals, with identified fractures according to described above advanced logging suit. In addition, pressure transient analysis was performed, to measure the formation pressure, define pressure gradient curves and assess the fluids contact level with high confidence, for the first time for this field.","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"24 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88004551","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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