V. Nagimov, V. Virt, V. Kosolapov, D. Bakhitov, Yu. V. Maslennikova, L. Spirina, I. Shigapov
Cost-effective reservoir development of oil rims such as Novoportovskoe field requires improving of existing fracturing methods on a way to increase recovery factor. One of the approaches includes the implementation of special completion with renewable fracturing sleeves as well as increasing the number of fracture ports over horizontal wellbore (Belov and others, 2018). This allows to increase profitability from one side, but from the other side, considering the complexity of oil rims geology, this increases the risks of early gas and water breakthrough from the gas cap and water contact respectively via hydraulic fractures induced to untargeted intervals. Generally, the efficiency of implemented well completion design is evaluated based on conventional production logging, however, high resolution and sensitive well diagnostics are required in case of a high number of fracture ports. An additional challenge is associated with diagnostics of flow in the reservoir behind the liner and completion components integrity evaluation such as packer and fracture sleeves. The better diagnostics is applied the more efficient production profile optimization can be done. The paper describes the through-barrier diagnostics concept and shows a case of the performed survey in a horizontal well to oil rim with 30-stage hydraulic fracturing based on through-barrier diagnostics. Two surveys were conducted: the first survey was done at an early stage of well production, then workover was performed based on the first survey results revealing several zones with high GOR and high water cut. The second survey was conducted after the workover. Additionally, the paper describes a novel method on high GOR and high WC zones identification from spectral acoustic data analysis based on machine learning.
{"title":"Efficiency Analysis of 30-Stage Fracturing in a Horizontal Well to Oil Rims Based on Through-Barrier Diagnostics","authors":"V. Nagimov, V. Virt, V. Kosolapov, D. Bakhitov, Yu. V. Maslennikova, L. Spirina, I. Shigapov","doi":"10.2118/196834-ms","DOIUrl":"https://doi.org/10.2118/196834-ms","url":null,"abstract":"\u0000 Cost-effective reservoir development of oil rims such as Novoportovskoe field requires improving of existing fracturing methods on a way to increase recovery factor. One of the approaches includes the implementation of special completion with renewable fracturing sleeves as well as increasing the number of fracture ports over horizontal wellbore (Belov and others, 2018). This allows to increase profitability from one side, but from the other side, considering the complexity of oil rims geology, this increases the risks of early gas and water breakthrough from the gas cap and water contact respectively via hydraulic fractures induced to untargeted intervals.\u0000 Generally, the efficiency of implemented well completion design is evaluated based on conventional production logging, however, high resolution and sensitive well diagnostics are required in case of a high number of fracture ports. An additional challenge is associated with diagnostics of flow in the reservoir behind the liner and completion components integrity evaluation such as packer and fracture sleeves. The better diagnostics is applied the more efficient production profile optimization can be done. The paper describes the through-barrier diagnostics concept and shows a case of the performed survey in a horizontal well to oil rim with 30-stage hydraulic fracturing based on through-barrier diagnostics. Two surveys were conducted: the first survey was done at an early stage of well production, then workover was performed based on the first survey results revealing several zones with high GOR and high water cut. The second survey was conducted after the workover. Additionally, the paper describes a novel method on high GOR and high WC zones identification from spectral acoustic data analysis based on machine learning.","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":"78531160","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
A. Aslanyan, B. Ganiev, A. Lutfullin, Maxim Shvydenko, I. Karimov, D. Gulyaev, V. Krichevsky, Rushana Farahova, L. Zinurov
The paper describes the first use of Multiwell Retrospective Test (MRT) on the Devonian formation of the Romashkinskoye oil field. The paper introduces the technology of MRT and describes the advantages in determining the interference of wells and formation pressure (4-7). The field case cited in the article describes a specific implementation of an MRT, called "radial deconvolution," in which the central (tested) well is equipped with a bottomhole pressure gauge. As a result, the interference of the offset injection and production wells to the tested well is estimated, as well as the properties of the well and reservoir, taking into account the interference with the offset wells. One of the advantages of this technology is the ability to estimate formation pressure without shutting the well. In this research, a comparative test was performed, in which the reservoir pressure predicted by MRT was checked with a field test.
{"title":"Assessing Efficiency of Multiwell Retrospective Testing MRT in Analysis of Cross-Well Interference and Prediction of Formation and Bottom- Hole Pressure Dynamics","authors":"A. Aslanyan, B. Ganiev, A. Lutfullin, Maxim Shvydenko, I. Karimov, D. Gulyaev, V. Krichevsky, Rushana Farahova, L. Zinurov","doi":"10.2118/196839-ms","DOIUrl":"https://doi.org/10.2118/196839-ms","url":null,"abstract":"\u0000 The paper describes the first use of Multiwell Retrospective Test (MRT) on the Devonian formation of the Romashkinskoye oil field.\u0000 The paper introduces the technology of MRT and describes the advantages in determining the interference of wells and formation pressure (4-7).\u0000 The field case cited in the article describes a specific implementation of an MRT, called \"radial deconvolution,\" in which the central (tested) well is equipped with a bottomhole pressure gauge. As a result, the interference of the offset injection and production wells to the tested well is estimated, as well as the properties of the well and reservoir, taking into account the interference with the offset wells. One of the advantages of this technology is the ability to estimate formation pressure without shutting the well. In this research, a comparative test was performed, in which the reservoir pressure predicted by MRT was checked with a field test.","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":"73727969","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}
In the study the main tendencies in fracture development in rock masses are investigated. The question of natural shear fractures' fluid conductivity is particularly analyzed as this question is important for development of hydrocarbon fields. The localization of the majority of hydraulically conductive fractures in the reservoir and their preferable spatial orientations are analyzed based on the hypothesis of an existing relationship between current stress state of the rock mass and the fractures' hydraulic conductivity. A mathematical algorithm for solving the forward problem of finding all possible spatial orientations of hydraulically conductive fractures for an arbitrary stress tensor is proposed. Stereonets are used as a tool for interpreting the spatial orientations of fractures. The proposed algorithm is used to find the main tendencies in hydraulically conductive fractures' spatial orientations for the following cases: gradual increase of the considered object's depth; gradual change of one of the principal stresses; case of approaching a large fault. A relationship between typical behavior of the fractures and stress regime in the region is found out alongside with typical changes in spatial orientations of hydraulically conductive fractures while approaching faults of different types. The obtained results may be directly used for planning the development of oil fields, characterized by a considerable contribution of fractures to permeability. The results are particularly important for development of fractured zones in vicinities of large faults. Moreover, the proposed algorithm of finding the geometrical properties of hydraulically conductive fractures may be applied based on results of three- and four-dimensional geomechanical modeling carried out for particular fields providing an opportunity to both determine the zones being perspective for development, and predict the changes of these zones' properties during reservoir development.
{"title":"Patterns of Hydraulically Conductive Fractures' Positions and Spatial Orientations Near Large Faults","authors":"Nikita Vladislavovich Dubinya","doi":"10.2118/196900-ms","DOIUrl":"https://doi.org/10.2118/196900-ms","url":null,"abstract":"\u0000 In the study the main tendencies in fracture development in rock masses are investigated. The question of natural shear fractures' fluid conductivity is particularly analyzed as this question is important for development of hydrocarbon fields. The localization of the majority of hydraulically conductive fractures in the reservoir and their preferable spatial orientations are analyzed based on the hypothesis of an existing relationship between current stress state of the rock mass and the fractures' hydraulic conductivity. A mathematical algorithm for solving the forward problem of finding all possible spatial orientations of hydraulically conductive fractures for an arbitrary stress tensor is proposed. Stereonets are used as a tool for interpreting the spatial orientations of fractures. The proposed algorithm is used to find the main tendencies in hydraulically conductive fractures' spatial orientations for the following cases: gradual increase of the considered object's depth; gradual change of one of the principal stresses; case of approaching a large fault. A relationship between typical behavior of the fractures and stress regime in the region is found out alongside with typical changes in spatial orientations of hydraulically conductive fractures while approaching faults of different types. The obtained results may be directly used for planning the development of oil fields, characterized by a considerable contribution of fractures to permeability. The results are particularly important for development of fractured zones in vicinities of large faults. Moreover, the proposed algorithm of finding the geometrical properties of hydraulically conductive fractures may be applied based on results of three- and four-dimensional geomechanical modeling carried out for particular fields providing an opportunity to both determine the zones being perspective for development, and predict the changes of these zones' properties during reservoir development.","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":"81188793","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}
Timur Arbatsky, A. Shchurenko, N. Dadakin, M. Nukhayev, I. Yamalov, K. Rymarenko
The paper presents the experience of oil and gas exploration in the fields of the Irkutsk region. The geological features of the studied facilities dictate a practical approach and the use of compact and efficient technological solutions that can later be successfully applied to a large number of fields with similar geology. The paper highlighted an optimized complex of works on the development and testing of wells target objects in a cased wellbore, using the technology of "the well shut-off at the bottomhole". This arrangement ensures the effective implementation of work on the development of target objects and allows for high-quality registration of the bottomhole pressure dynamics. This engineering solution allows to perform a full cycle of hydrodynamical studies of well (well test) for a target interval in a relatively short time. The use of a tube bank significantly reduces the wellbore storage eand allows to obtain detailed data reliably characterizing reservoir properties and the structure of the reservoir under study. The article describes the technology of hydrodynamic studies, with the well shut-off at the bottomhole. The article deals with the research problems of highly productive, flowing facilities, with a concrete example and a detailed analysis of technological features, interpretation options, possible complications and measures for optimization. The possibility of replicating technology in various geological and technical conditions is considered.
{"title":"Application Rationale of Well Flow Test Complex Modules Covering Well Shut-in at the Bottomhole in terms of Eastern Siberia Carbonate Reservoirs Study","authors":"Timur Arbatsky, A. Shchurenko, N. Dadakin, M. Nukhayev, I. Yamalov, K. Rymarenko","doi":"10.2118/196832-ms","DOIUrl":"https://doi.org/10.2118/196832-ms","url":null,"abstract":"\u0000 The paper presents the experience of oil and gas exploration in the fields of the Irkutsk region. The geological features of the studied facilities dictate a practical approach and the use of compact and efficient technological solutions that can later be successfully applied to a large number of fields with similar geology. The paper highlighted an optimized complex of works on the development and testing of wells target objects in a cased wellbore, using the technology of \"the well shut-off at the bottomhole\".\u0000 This arrangement ensures the effective implementation of work on the development of target objects and allows for high-quality registration of the bottomhole pressure dynamics. This engineering solution allows to perform a full cycle of hydrodynamical studies of well (well test) for a target interval in a relatively short time. The use of a tube bank significantly reduces the wellbore storage eand allows to obtain detailed data reliably characterizing reservoir properties and the structure of the reservoir under study.\u0000 The article describes the technology of hydrodynamic studies, with the well shut-off at the bottomhole. The article deals with the research problems of highly productive, flowing facilities, with a concrete example and a detailed analysis of technological features, interpretation options, possible complications and measures for optimization. The possibility of replicating technology in various geological and technical conditions is considered.","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":"74540126","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}
The present time is characterized by increased number of features with complex geology and poor exploration maturity where the target interval is represented by thin pays and heavy lithologic heterogeneity. In most cases, seismic inversion is used to prospect such features; however, quality seismic inversion calculation is quite a labor-and-resource intensive process; given the increasing demand for the acceleration of exploration projects and fast provision of spud-in locations, the need arises for the development and provision of an inversion-building method whose quality would be no worse than that of syncronous inversion and which could be done faster. This manuscript aims at the developing and benchmarking of a new approach to acoustic impedance forecast. The manuscript describes an acoustic impedance reconstruction algorithm built on wavefield spectral inversion and allowed for low-frequency model based on well logs. To prove its applicability, we tested it using model data, as well as based on an East Siberian field case as part of which the accuracy of reconstruction properties was benchmarked using standard and suggested approach.
{"title":"Using Spectral Inversion to Build Acoustic Impedance Exemplified by an East Sibirian Field","authors":"Veronica Fagreeva, A. Butorin, F. Krasnov","doi":"10.2118/196780-ms","DOIUrl":"https://doi.org/10.2118/196780-ms","url":null,"abstract":"\u0000 The present time is characterized by increased number of features with complex geology and poor exploration maturity where the target interval is represented by thin pays and heavy lithologic heterogeneity.\u0000 In most cases, seismic inversion is used to prospect such features; however, quality seismic inversion calculation is quite a labor-and-resource intensive process; given the increasing demand for the acceleration of exploration projects and fast provision of spud-in locations, the need arises for the development and provision of an inversion-building method whose quality would be no worse than that of syncronous inversion and which could be done faster.\u0000 This manuscript aims at the developing and benchmarking of a new approach to acoustic impedance forecast. The manuscript describes an acoustic impedance reconstruction algorithm built on wavefield spectral inversion and allowed for low-frequency model based on well logs. To prove its applicability, we tested it using model data, as well as based on an East Siberian field case as part of which the accuracy of reconstruction properties was benchmarked using standard and suggested approach.","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":"90969949","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
V. N. Averkin, Andrey Krylov, Petr Leonidovich Ryabtsev, Yury Valerievich Lukovkin
Oil-base drilling fluids provide considerable advantages, however they have a number of limitations mainly related to drilling fluid system contamination with drill solids and formation water. The primary objective is to remove solids from the drilling fluid during the first cycle of their entering into the system in the course of well lengthening. These solids are defined as the concentration of suspended particles. Current solids control equipment does not remove the generated drill cuttings due to the absence of the first stage of solids control – shale shakers; therefore the cuttings transform into fine solids and accumulate as colloidal particles causing the growth of the concentration of suspended particles and reducing reservoir drilling-in quality. To meet the requirement, i.e. quality reservoir drilling-in, it is necessary to ensure effective cuttings removal during the first cycle of their movement. In 2018 Surgutneftegaz planned and performed field tests of the AKROS coagulant for solids (hereinafter – Coagulant) at the Talakanneft Field Office. The test results enabled conclusions on specific features of the Coagulant use in the drilling fluid – crude oil (hereinafter – crude oil) and identification of the potential for reservoir drilling-in optimization that may expand its applicability. As part of the New Technological Solution Implementation Program at Surgutneftegaz fields, additional lab equipment was used to obtain extended data, enabling a new interpretation of multilateral well lengthening. A lengthened multilateral well was drilled at a Surgutneftegaz field using the Coagulant. Coagulant field test results enabled the following improvements in drilling performance indicators: –reduced torque;–reduced tool weight during pulling out;–improved transfer of load to drilling tool;–increased ROP;–reduced concentration of suspended particles;–removal of formation water from crude oil. Results achieved on the concentration of suspended particles allow the transfer of crude oil to the following well/interval upon the completion of well lengthening or its injection into an oil reservoir with the minimum concentration of suspended particles. Crude oil treatment with the Coagulant will mitigate risks of heating elements failure, reduce the crude oil volume used for well lengthening, and ensure its reuse without additional replacements and/or dilutions. The use of the Coagulant demonstrated the ability to reduce the swelling activity of anhydrite occurring in the producing formation when it comes in contact with water contained in the crude oil, making well lengthening operations more technological. Results of the Coagulant use enabled the development of field practices of its application and recommendations on crude oil properties control as well as performance of comparative analysis of the efficiency of solids content reduction and water phase de-emulsification in the crude oil.
{"title":"First Use of Coagulant for Solids in the Drilling Fluid Crude Oil for Underbalanced Drilling in Russia","authors":"V. N. Averkin, Andrey Krylov, Petr Leonidovich Ryabtsev, Yury Valerievich Lukovkin","doi":"10.2118/196801-ms","DOIUrl":"https://doi.org/10.2118/196801-ms","url":null,"abstract":"\u0000 Oil-base drilling fluids provide considerable advantages, however they have a number of limitations mainly related to drilling fluid system contamination with drill solids and formation water. The primary objective is to remove solids from the drilling fluid during the first cycle of their entering into the system in the course of well lengthening. These solids are defined as the concentration of suspended particles. Current solids control equipment does not remove the generated drill cuttings due to the absence of the first stage of solids control – shale shakers; therefore the cuttings transform into fine solids and accumulate as colloidal particles causing the growth of the concentration of suspended particles and reducing reservoir drilling-in quality. To meet the requirement, i.e. quality reservoir drilling-in, it is necessary to ensure effective cuttings removal during the first cycle of their movement.\u0000 In 2018 Surgutneftegaz planned and performed field tests of the AKROS coagulant for solids (hereinafter – Coagulant) at the Talakanneft Field Office. The test results enabled conclusions on specific features of the Coagulant use in the drilling fluid – crude oil (hereinafter – crude oil) and identification of the potential for reservoir drilling-in optimization that may expand its applicability.\u0000 As part of the New Technological Solution Implementation Program at Surgutneftegaz fields, additional lab equipment was used to obtain extended data, enabling a new interpretation of multilateral well lengthening.\u0000 A lengthened multilateral well was drilled at a Surgutneftegaz field using the Coagulant.\u0000 Coagulant field test results enabled the following improvements in drilling performance indicators: –reduced torque;–reduced tool weight during pulling out;–improved transfer of load to drilling tool;–increased ROP;–reduced concentration of suspended particles;–removal of formation water from crude oil.\u0000 Results achieved on the concentration of suspended particles allow the transfer of crude oil to the following well/interval upon the completion of well lengthening or its injection into an oil reservoir with the minimum concentration of suspended particles. Crude oil treatment with the Coagulant will mitigate risks of heating elements failure, reduce the crude oil volume used for well lengthening, and ensure its reuse without additional replacements and/or dilutions.\u0000 The use of the Coagulant demonstrated the ability to reduce the swelling activity of anhydrite occurring in the producing formation when it comes in contact with water contained in the crude oil, making well lengthening operations more technological. Results of the Coagulant use enabled the development of field practices of its application and recommendations on crude oil properties control as well as performance of comparative analysis of the efficiency of solids content reduction and water phase de-emulsification in the crude oil.","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":"88933601","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}
Sergey Zimovets, Alexandr Zhylin, V. Zlodeev, M. Kochergin, M. Levchenko, Anton Zhylin, A. Vasilyev, Pavel Sukharev, Maxim Bardin
An electromagnetic downhole tool with mathematically complete azimuthal sensitivity capable to determine the direction and the distance to the formation boundary at a distance of up to 6 meters has been developed. The tool was specifically designed for proactive geonavigation while drilling horizontal and highly inclined wells in difficult geological conditions. Mathematically complete measurements in the plane transverse to the tool axis allow to detect the boundaries without rotation of a drill string. The tool was carefully simulated, designed, developed and documented. Experimental prototype was assembled and tested. The engineering prototype manufacturing is in progress.
{"title":"New Electromagnetic Tool with Azimuthal Sensitivity Development for Proactive Geosteering While Drilling","authors":"Sergey Zimovets, Alexandr Zhylin, V. Zlodeev, M. Kochergin, M. Levchenko, Anton Zhylin, A. Vasilyev, Pavel Sukharev, Maxim Bardin","doi":"10.2118/196777-ms","DOIUrl":"https://doi.org/10.2118/196777-ms","url":null,"abstract":"\u0000 An electromagnetic downhole tool with mathematically complete azimuthal sensitivity capable to determine the direction and the distance to the formation boundary at a distance of up to 6 meters has been developed. The tool was specifically designed for proactive geonavigation while drilling horizontal and highly inclined wells in difficult geological conditions. Mathematically complete measurements in the plane transverse to the tool axis allow to detect the boundaries without rotation of a drill string.\u0000 The tool was carefully simulated, designed, developed and documented. Experimental prototype was assembled and tested. The engineering prototype manufacturing is in progress.","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":"87761268","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. Vikhman, A. Barinov, D. Kolupaev, N. Chebykin, R. Uchuev, U. Mavletkulov, S. Vereschagin, S. Pavlova, S. Sypchenko, D. Valnev
The South-Priobskoe Field is one of the largest oil pools in Western Siberia, with a unique category of reserves. Due to the low filtration properties of the productive formations AS10-AS12 (permeability of which is not more than 3 mD), the drilling of horizontal wells with subsequent multi-stage hydraulic fracturing (MSHF) completion is the most cost-effective way in this case. The use of highly viscous fracture fluids (at least 400 cP at 100 s-1) and 16/20 mesh proppant with a maximum concentration of 800-900 kg/m3 and the slurry rates are not exceeding 4.0 m3/min, became a kind of standard during the MSHF. However, a steady decline of permeability in the newly drilled areas of the field is observed (below 0.5 mD), because of this, an effective half-length of cracks begins to make an increasing contribution to oil production. This paper describes the introduction of non-standard methods of hydraulic fracturing for a traditional reservoir, and an idea was the use of low-viscous fluids with increased slurry rates, which resulted in an increase in well production rates by an average of 7%.
{"title":"High Rate Hybrid Fracturing in South-Priobskoe Field","authors":"I. Vikhman, A. Barinov, D. Kolupaev, N. Chebykin, R. Uchuev, U. Mavletkulov, S. Vereschagin, S. Pavlova, S. Sypchenko, D. Valnev","doi":"10.2118/196973-ms","DOIUrl":"https://doi.org/10.2118/196973-ms","url":null,"abstract":"\u0000 The South-Priobskoe Field is one of the largest oil pools in Western Siberia, with a unique category of reserves. Due to the low filtration properties of the productive formations AS10-AS12 (permeability of which is not more than 3 mD), the drilling of horizontal wells with subsequent multi-stage hydraulic fracturing (MSHF) completion is the most cost-effective way in this case. The use of highly viscous fracture fluids (at least 400 cP at 100 s-1) and 16/20 mesh proppant with a maximum concentration of 800-900 kg/m3 and the slurry rates are not exceeding 4.0 m3/min, became a kind of standard during the MSHF. However, a steady decline of permeability in the newly drilled areas of the field is observed (below 0.5 mD), because of this, an effective half-length of cracks begins to make an increasing contribution to oil production. This paper describes the introduction of non-standard methods of hydraulic fracturing for a traditional reservoir, and an idea was the use of low-viscous fluids with increased slurry rates, which resulted in an increase in well production rates by an average of 7%.","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":"79111547","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. Kurbanov, A. Rotaru, V. Gribanov, R. Bakhitov, Yuliy Sidorov
One of the main problems associated with drilling of the horizontal wells of high length under conditions of a low-porous carbonate fractured reservoir is catastrophic mud losses associated with zones of intense fracturing and cavernousness. The meeting of such zones leads to the risk of failure to achieve the project well length, which further negatively affects the reserves development. This article describes the technological, production, economic aspects of the introduction of managed pressure drilling (MPD). Managed Pressure Drilling (MPD) is an adaptive drilling process used to precise control the annular pressure profile throughout the wellbore. While conventional drilling uses the hydrostatic pressure of the drilling mud to manage pressure in the well, MPD uses a combination of surface pressure, hydrostatic pressure of the mud and annular friction to balance the exposed formation pressure. Control of these parameters allows maintaining the pressure at the bottom of the well close to the reservoir pressure, thereby avoiding mud losses or inflow of formation fluid into the well. Conventional drilling of highly fractured zone is accompanied with intensive mud losses. Over 50% of the drilled wells in the oilfield could not reach the final target. Average productivity index for short wells is 30% less than for those that reached planned horizontal length. Application of bridging agents and hi-vis pills partially allows to solve the problem, but negatively affects the productivity and cost of wells. As part of pilot stage, managed pressure drilling was tested on the two well clusters. 5 wells out of 7 reached the project length. The increase in the starting oil rate was 30%. The loss of drilling mud has significantly decreased. The average mechanical rate of penetration increased by 7%. Despite the high cost of the MPD, the ability to control the well during drilling reduces the final cost of the well by minimizing the loss of oil required to prepare the drilling fluid. According to the analyzed wells, the average cost of a meter of penetration for MPD is 14% higher than with standard overbalance drilling. At the same time, the unit cost of drilling per one ton of oil flow rate decreased by 22%, which indicates the economic feasibility of the technology. The paper presents a comprehensive analysis of the MPD, with an assessment of the impact on drilling performance (rate of penetration, mud loses), production characteristics of wells (starting production rate, productivity index) and economic effect (cost of 1m penetration).
{"title":"Managed Pressure Drilling Overcomes Drilling Challenges and Enhances Oil Production of Naturally Fractured Carbonate Reservoir of East Siberia","authors":"V. Kurbanov, A. Rotaru, V. Gribanov, R. Bakhitov, Yuliy Sidorov","doi":"10.2118/196790-ms","DOIUrl":"https://doi.org/10.2118/196790-ms","url":null,"abstract":"\u0000 One of the main problems associated with drilling of the horizontal wells of high length under conditions of a low-porous carbonate fractured reservoir is catastrophic mud losses associated with zones of intense fracturing and cavernousness. The meeting of such zones leads to the risk of failure to achieve the project well length, which further negatively affects the reserves development. This article describes the technological, production, economic aspects of the introduction of managed pressure drilling (MPD).\u0000 Managed Pressure Drilling (MPD) is an adaptive drilling process used to precise control the annular pressure profile throughout the wellbore. While conventional drilling uses the hydrostatic pressure of the drilling mud to manage pressure in the well, MPD uses a combination of surface pressure, hydrostatic pressure of the mud and annular friction to balance the exposed formation pressure. Control of these parameters allows maintaining the pressure at the bottom of the well close to the reservoir pressure, thereby avoiding mud losses or inflow of formation fluid into the well.\u0000 Conventional drilling of highly fractured zone is accompanied with intensive mud losses. Over 50% of the drilled wells in the oilfield could not reach the final target. Average productivity index for short wells is 30% less than for those that reached planned horizontal length. Application of bridging agents and hi-vis pills partially allows to solve the problem, but negatively affects the productivity and cost of wells.\u0000 As part of pilot stage, managed pressure drilling was tested on the two well clusters. 5 wells out of 7 reached the project length. The increase in the starting oil rate was 30%. The loss of drilling mud has significantly decreased. The average mechanical rate of penetration increased by 7%. Despite the high cost of the MPD, the ability to control the well during drilling reduces the final cost of the well by minimizing the loss of oil required to prepare the drilling fluid. According to the analyzed wells, the average cost of a meter of penetration for MPD is 14% higher than with standard overbalance drilling. At the same time, the unit cost of drilling per one ton of oil flow rate decreased by 22%, which indicates the economic feasibility of the technology.\u0000 The paper presents a comprehensive analysis of the MPD, with an assessment of the impact on drilling performance (rate of penetration, mud loses), production characteristics of wells (starting production rate, productivity index) and economic effect (cost of 1m penetration).","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":"75345047","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}
P. Dobrokhleb, A. Truba, S. Borges, I. Moiseenko, Anatoly Vorozheykin, A. Dotsenko, S. A. Evdokimov, Andrey Niverchuk, Timur Khusaenov, A. Kurasov, R. Davletov, G. Galaktionov, E. Glebov, Ivan V. Shokarev, M. Grigoriev, D. Sidorov, Alexey Zhludov
The Yurkharovskoye oil and gas condensate field is one of the main asset of PJSC NOVATEK. Two of the three productive levels (Cenoman and Valangin) are in the active development phase. The Jurassic reservoir, which is characterized by complex geology, high formation pressure (gradient ~ 2.0MPa / 100m) and a low fracturing gradient (FG), is currently in the exploration phase. In 2017, drilling of the first exploration well with a depth of 4855 m with a horizontal ending with multistage formation fracturing in the Jurassic formation was successfully completed. Successful completion of the drilling allowed not only to obtain valuable geological information, but also to choose an approach to the construction of such wells in the future. Joint efforts of the field operator, drilling contractor and oilfield services company have developed a drilling system that included a full range of engineering solutions that ensure an efficient and accident-free well construction process: completion, directional drilling, bits, drilling fluids, geomechanics and managed pressure drilling (MPD). Previous experience in the construction of directional wells was associated with mud losses due to fracturing, blow outs and wellbore collapse. At the design planning stage, the well design was optimized, the completion system was developed, the formulations of high-density drilling muds with low rheology were selected, a choice of technologies was made and much more. Each stage of the well construction was worked out and a scheme of operative interaction between the parties was developed, which allowed timely correction of the work program based on an actual information. Even at the design planning stage geomechanical modeling allowed design optimization and choose a safe trajectory of the well, and its update, based on the actual information, allowed to reduce the risks. Specially for this well, the formulation of the hydrocarbon-based solution was developed, which, despite its high density, was distinguished by low rheological properties. An important aspect of the preparation was the selection of bottomhole assembly and drilling regimes, which, on the one hand, should ensure efficient drilling, and on the other, generate the smallest possible equivalent circulation density (ECD). The use of MPD technology has made possible to maintain the ECD and ESP (equivalent static pressure) at the same level and to compensate for the pressure fluctuations during circulation and movement of the drill string while trips. To select the BHA, a special program complex was used to simulate the dynamics of its behavior at the bottomhole. Logging tools at BHA provided important real-time information that was used to manage the drilling process and make operational decisions. The hybrid rotary steerable system (RSS) allowed to drill the well in the riskiest intervals with a minimum angle and to provide a high dog leg and hit the target. The completion system for multistage fracturing with s
{"title":"High Technologies – New Opportunities for Horizontal Drilling on Jurassic Formations in Complex Conditions of HTHP and Narrow Safe Mud Window","authors":"P. Dobrokhleb, A. Truba, S. Borges, I. Moiseenko, Anatoly Vorozheykin, A. Dotsenko, S. A. Evdokimov, Andrey Niverchuk, Timur Khusaenov, A. Kurasov, R. Davletov, G. Galaktionov, E. Glebov, Ivan V. Shokarev, M. Grigoriev, D. Sidorov, Alexey Zhludov","doi":"10.2118/196798-MS","DOIUrl":"https://doi.org/10.2118/196798-MS","url":null,"abstract":"The Yurkharovskoye oil and gas condensate field is one of the main asset of PJSC NOVATEK. Two of the three productive levels (Cenoman and Valangin) are in the active development phase. The Jurassic reservoir, which is characterized by complex geology, high formation pressure (gradient ~ 2.0MPa / 100m) and a low fracturing gradient (FG), is currently in the exploration phase. In 2017, drilling of the first exploration well with a depth of 4855 m with a horizontal ending with multistage formation fracturing in the Jurassic formation was successfully completed. Successful completion of the drilling allowed not only to obtain valuable geological information, but also to choose an approach to the construction of such wells in the future. Joint efforts of the field operator, drilling contractor and oilfield services company have developed a drilling system that included a full range of engineering solutions that ensure an efficient and accident-free well construction process: completion, directional drilling, bits, drilling fluids, geomechanics and managed pressure drilling (MPD). Previous experience in the construction of directional wells was associated with mud losses due to fracturing, blow outs and wellbore collapse. At the design planning stage, the well design was optimized, the completion system was developed, the formulations of high-density drilling muds with low rheology were selected, a choice of technologies was made and much more. Each stage of the well construction was worked out and a scheme of operative interaction between the parties was developed, which allowed timely correction of the work program based on an actual information. Even at the design planning stage geomechanical modeling allowed design optimization and choose a safe trajectory of the well, and its update, based on the actual information, allowed to reduce the risks. Specially for this well, the formulation of the hydrocarbon-based solution was developed, which, despite its high density, was distinguished by low rheological properties. An important aspect of the preparation was the selection of bottomhole assembly and drilling regimes, which, on the one hand, should ensure efficient drilling, and on the other, generate the smallest possible equivalent circulation density (ECD). The use of MPD technology has made possible to maintain the ECD and ESP (equivalent static pressure) at the same level and to compensate for the pressure fluctuations during circulation and movement of the drill string while trips. To select the BHA, a special program complex was used to simulate the dynamics of its behavior at the bottomhole. Logging tools at BHA provided important real-time information that was used to manage the drilling process and make operational decisions. The hybrid rotary steerable system (RSS) allowed to drill the well in the riskiest intervals with a minimum angle and to provide a high dog leg and hit the target. The completion system for multistage fracturing with s","PeriodicalId":10977,"journal":{"name":"Day 2 Wed, October 23, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-01-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77220580","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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