One of the main challenges from operating companies is the continuous reduction of well construction time. During drilling, considerable time is spent on static measurements to determine the wellbore location and to verify that the actual well path matches the planned one. The electromagnetic telemetry system (EMT) allows the taking of static directional survey measurements during connections, when the drill string is in slips. Transmitting commands to the rotary steerable system (RSS) through the EMT does not cause the drilling process to stop, which also reduces well construction time. The work describes well drilling experience with the use of the electromagnetic channel for communication with the rotary steerable system and the positive displacement downhole motor not only in horizontal section but in all well sections, starting from the top hole. Combined use of the complete logging while drilling tools (LWD) with this type of the telemetry system is a valuable finding. The article describes BHA, operational principles of this type of the telemetry system, and problems which may arise during operation.
{"title":"Continuous Improvement: Rotary Steerable System with Electromagnetic Telemetry as Approach to Reduce Well Time","authors":"Farit Rakhmangulov, Pavel Dorokhin","doi":"10.2118/206441-ms","DOIUrl":"https://doi.org/10.2118/206441-ms","url":null,"abstract":"\u0000 One of the main challenges from operating companies is the continuous reduction of well construction time. During drilling, considerable time is spent on static measurements to determine the wellbore location and to verify that the actual well path matches the planned one. The electromagnetic telemetry system (EMT) allows the taking of static directional survey measurements during connections, when the drill string is in slips. Transmitting commands to the rotary steerable system (RSS) through the EMT does not cause the drilling process to stop, which also reduces well construction time.\u0000 The work describes well drilling experience with the use of the electromagnetic channel for communication with the rotary steerable system and the positive displacement downhole motor not only in horizontal section but in all well sections, starting from the top hole. Combined use of the complete logging while drilling tools (LWD) with this type of the telemetry system is a valuable finding. The article describes BHA, operational principles of this type of the telemetry system, and problems which may arise during operation.","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"70 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84757278","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}
Rasoul Nazari, Nurlan Zhulomanov, M. Van Doorn, Auribel Dos Santos, Nurbek Medeuov
Stimulation systems have improved over past decades, yet challenges prevail in corrosion, unwanted precipitation and handling hazardous chemicals. The role of chelating agents in coping with such concerns, is undeniably positive: their limited corrosivity, effective metal control and outstanding HSE profile, make them effective acidizing alternatives. Particularly when seeking delayed reaction at high temperature or removing insoluble material like Barite, chelating agents like GLDA and DTPA respectively have been reported effective both at laboratory and field scale. Formulations based on abovementioned chelating agents were evaluated experimentally to assess potential stimulation of Kazakhstan formations. Core-plug samples used in this evaluation are predominantly carbonate rock originating from different wells. The coreflooding experiments were performed at HPHT conditions to assess performance of treatment fluids to a) create new flow-channels (wormholes) thus improving rock permeability, and b) remove BaSO4-based solids suspected to be affecting productivity in the field. In this work, five reservoir core plugs were stimulated by GLDA based formulation to assess wormholing mechanism, while two core-plugs were treated by DTPA based fluid to study the impact of matrix cleaning. The matrix cleaning properties of DTPA based fluid were investigated on the damaged core plugs which were artificially damaged by in-situ precipitation of BaSO4 scale. The coreflood study included injection of the preflush, the treatment fluid and the post-flush system at reservoir temperature of 270 °F and low injection rates to accommodate the low permeability of the formation. It was shown that GLDA based fluid can effectively stimulate the reservoir core samples. The effective mechanism was observed to be wormholing thus increasing rock permeability by over a thousand times. No signs of face dissolution were observed despite slow injection rate at such high temperature; something that was not possible when a fast reacting acid (i.e. HCl) was used under the same conditions. In addition, it was shown that the DTPA based fluid can efficiently improve the rock permeability through matrix cleaning by both Barium and Calcium chelation. In the first treatment test by this fluid system, around 45% of the damaged permeability was recovered. While in the second test, not only BaSO4 scale was dissolved but also the CaCO3 minerals were partly dissolved and the core permeability was significantly increased (Kf/Ki >200). Experimental results bring promising prognosis for field implementation despite expected low injectivity at high downhole temperature. GLDA treatments avoid premature acid spending and face dissolution - common outcomes of HCl- which translate into deeper extent of stimulation. Additionally, in barite damaged wells, DTPA treatment represents an attractive solution for damage reduction and by-passing. Finally, intrinsic properties of chelating agents reduce
{"title":"Stimulation of Tight Formation in Kazakhstan by Chelate Based Treatment Fluids","authors":"Rasoul Nazari, Nurlan Zhulomanov, M. Van Doorn, Auribel Dos Santos, Nurbek Medeuov","doi":"10.2118/206646-ms","DOIUrl":"https://doi.org/10.2118/206646-ms","url":null,"abstract":"\u0000 Stimulation systems have improved over past decades, yet challenges prevail in corrosion, unwanted precipitation and handling hazardous chemicals. The role of chelating agents in coping with such concerns, is undeniably positive: their limited corrosivity, effective metal control and outstanding HSE profile, make them effective acidizing alternatives. Particularly when seeking delayed reaction at high temperature or removing insoluble material like Barite, chelating agents like GLDA and DTPA respectively have been reported effective both at laboratory and field scale.\u0000 Formulations based on abovementioned chelating agents were evaluated experimentally to assess potential stimulation of Kazakhstan formations. Core-plug samples used in this evaluation are predominantly carbonate rock originating from different wells. The coreflooding experiments were performed at HPHT conditions to assess performance of treatment fluids to a) create new flow-channels (wormholes) thus improving rock permeability, and b) remove BaSO4-based solids suspected to be affecting productivity in the field. In this work, five reservoir core plugs were stimulated by GLDA based formulation to assess wormholing mechanism, while two core-plugs were treated by DTPA based fluid to study the impact of matrix cleaning.\u0000 The matrix cleaning properties of DTPA based fluid were investigated on the damaged core plugs which were artificially damaged by in-situ precipitation of BaSO4 scale. The coreflood study included injection of the preflush, the treatment fluid and the post-flush system at reservoir temperature of 270 °F and low injection rates to accommodate the low permeability of the formation.\u0000 It was shown that GLDA based fluid can effectively stimulate the reservoir core samples. The effective mechanism was observed to be wormholing thus increasing rock permeability by over a thousand times. No signs of face dissolution were observed despite slow injection rate at such high temperature; something that was not possible when a fast reacting acid (i.e. HCl) was used under the same conditions. In addition, it was shown that the DTPA based fluid can efficiently improve the rock permeability through matrix cleaning by both Barium and Calcium chelation. In the first treatment test by this fluid system, around 45% of the damaged permeability was recovered. While in the second test, not only BaSO4 scale was dissolved but also the CaCO3 minerals were partly dissolved and the core permeability was significantly increased (Kf/Ki >200).\u0000 Experimental results bring promising prognosis for field implementation despite expected low injectivity at high downhole temperature. GLDA treatments avoid premature acid spending and face dissolution - common outcomes of HCl- which translate into deeper extent of stimulation. Additionally, in barite damaged wells, DTPA treatment represents an attractive solution for damage reduction and by-passing. Finally, intrinsic properties of chelating agents reduce ","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"114 13","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"91403678","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. Rebrikov, Anton Anatolyevich Koschenkov, Anastasiya Gennadievna Rakina, Igor Dmitrievich Kortunov, N. Koshelev, Maxim Petrovich Dubrovskiy, Vladimir Olegovich Bekasov, Yuriy Anatolyevich Yakimov, Pavel Anatolyevich Grechikho, M. A. Ataev
Currently, production and exploration drilling has entered a stage of development where one of the highest priority goals is to reduce the time for well construction with new technologies and innovations. One of the key components in this aspect is the utilizing of the latest achievements in the design and manufacture of rock cutting tools – drill bits. This article presents some new ideas on methods for identifying different types of vibrations when drilling with PDC bits using a system of sensors installed directly into the bit itself. In the oil and gas fields of Eastern Siberia, one of the main reasons for ineffective drilling with PDC bits are vibrations, which lead to premature wear of the cutting structure of the bit and the achievement of low ROPs in the dolomite and dolerite intervals. For efficient drilling of wells of various trajectories with a bottom hole assembly (BHA), including a downhole motor (PDM) and a PDC bit, special attention is paid to control of the bit by limiting the depth of cut, as well as the level of vibrations that occur during drilling process. Often, the existing complex of surface and BHA equipment fails to identify vibrations that occur directly on the bit, as well as to establish the true cause of their occurrence. Therefore, as an innovative solution to this problem, a system of sensors installed directly into the bit itself is proposed. The use of such a system makes it possible to determine the drilling parameters, differentiated depending on the lithological properties of rocks, leading to an increase in vibration impact. Together with the Operators, tests have been successfully carried out, which have proven the effectiveness of the application of this technology. The data obtained during the field tests made it possible to determine the type and source of vibration very accurately during drilling. In turn, this made it possible to precisely adjust the drilling parameters according to the drilled rocks, to draw up a detailed road map of effective drilling in a specific interval. Correction of drilling parameters based on the analysis of data obtained from sensors installed in the bit made it possible to reduce the resulting wear of the PDC bit cutting structure and, if necessary, make changes to the bit design to improve the technical and economic indicators. Thus, the use of a system of sensors for measuring the drilling parameters in a bit ensured the dynamic stability of the entire BHA at the bottomhole when drilling in rocks of different hardness, significantly reduced the wear of the drilling tools and qualitatively improved the drilling performance.
{"title":"The Use of a Sensor Modules System for Measuring Drilling Parameters in a Bit, Significantly Reduces the Construction Time of Wells in Eastern Siberia","authors":"A. Rebrikov, Anton Anatolyevich Koschenkov, Anastasiya Gennadievna Rakina, Igor Dmitrievich Kortunov, N. Koshelev, Maxim Petrovich Dubrovskiy, Vladimir Olegovich Bekasov, Yuriy Anatolyevich Yakimov, Pavel Anatolyevich Grechikho, M. A. Ataev","doi":"10.2118/206437-ms","DOIUrl":"https://doi.org/10.2118/206437-ms","url":null,"abstract":"\u0000 Currently, production and exploration drilling has entered a stage of development where one of the highest priority goals is to reduce the time for well construction with new technologies and innovations. One of the key components in this aspect is the utilizing of the latest achievements in the design and manufacture of rock cutting tools – drill bits. This article presents some new ideas on methods for identifying different types of vibrations when drilling with PDC bits using a system of sensors installed directly into the bit itself.\u0000 In the oil and gas fields of Eastern Siberia, one of the main reasons for ineffective drilling with PDC bits are vibrations, which lead to premature wear of the cutting structure of the bit and the achievement of low ROPs in the dolomite and dolerite intervals. For efficient drilling of wells of various trajectories with a bottom hole assembly (BHA), including a downhole motor (PDM) and a PDC bit, special attention is paid to control of the bit by limiting the depth of cut, as well as the level of vibrations that occur during drilling process. Often, the existing complex of surface and BHA equipment fails to identify vibrations that occur directly on the bit, as well as to establish the true cause of their occurrence. Therefore, as an innovative solution to this problem, a system of sensors installed directly into the bit itself is proposed. The use of such a system makes it possible to determine the drilling parameters, differentiated depending on the lithological properties of rocks, leading to an increase in vibration impact. Together with the Operators, tests have been successfully carried out, which have proven the effectiveness of the application of this technology.\u0000 The data obtained during the field tests made it possible to determine the type and source of vibration very accurately during drilling. In turn, this made it possible to precisely adjust the drilling parameters according to the drilled rocks, to draw up a detailed road map of effective drilling in a specific interval. Correction of drilling parameters based on the analysis of data obtained from sensors installed in the bit made it possible to reduce the resulting wear of the PDC bit cutting structure and, if necessary, make changes to the bit design to improve the technical and economic indicators. Thus, the use of a system of sensors for measuring the drilling parameters in a bit ensured the dynamic stability of the entire BHA at the bottomhole when drilling in rocks of different hardness, significantly reduced the wear of the drilling tools and qualitatively improved the drilling performance.","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"30 5","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"91419527","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}
Aleksander Valerievich Miroshnichenko, V. Korotovskikh, T. Musabirov, A. Fedorov, Khakim Khalilovich Suleimanov
The deterioration of the reservoir properties of potential oil and gas bearing areas on mature and green fields, as well as the increase in the volume of hard-to-recover reserves on low-permeable reservoirs set us new challenges in searching and using effective development technologies to maintain and even increase the oil production levels. Based on successful international experience, Russian oil and gas companies use horizontal wells (HW) with multi-stage hydraulic fracturing (MSHF) for the cost-effective development of low-permeable reservoirs. Thus, since the first pilot works of drilling technologies and completion of HW with MSHF in 2011, at the beginning of 2020, over 1,200 HW with MSHF were drilled and came on stream at the fields of LLC RN-Yuganskneftegaz, about half of which are at the exploitation play AS10-12 of the northern license territory (NLT) of the Priobskoye field. In searching the best technologies and engineering solutions, the company tested different lengths of horizontal section of HW, the number of hydraulic fracturing (HF) stages and distances between hydraulic fracturing ports, as well as different specific mass of the proppant per frac port. Recently, there has been a tendency in design solutions to increase the length of the HWs and the number of hydraulic fractures with a decreasing distance between the frac ports and a decreasing specific mass of the proppant per frac port. This work studies the actual and theoretical efficiency of HW with MSHF of various designs (different lengths of horizontal section of HW and the number of HF stages) and to assess the viability of increasing the technological complexity, as well as to analyze the actual impact of loading the proppant mass per port on performing HW with MSHF. The study is based on the results of the analysis of the factual experience accumulated over the entire history of the development of the exploitation play AS10-12 of the NLT of the Priobskoye field of the Rosneft Company. In studying the viability of increasing the technological complexity, especially, increasing the length of horizontal section of HW, increasing the number of HF stages, and reducing the distance between the frac ports: we discovered the typical methodological errors made in analyzing the efficiency of wells of various designs; we developed the methodology for analysis of the actual multiplicity of indicators of wells of various designs, in particular, HW with MSHF relative to deviated wells (DW) with HF; we carried out the statistical analysis of the actual values of the multiplicity of performance indicators and completion parameters of HW with MSHF of various designs relative to the surrounding DW with HF of the exploitation play AS10-12 of the NLT of the Priobskoye field; we performed the theoretical calculation of the multiplicity of the productivity coefficient for the HW with MSHF of various designs relative to DW with HF for the standard development system of the exploitati
{"title":"Investigation of Horizontal Wells with Multi-Stage Hydraulic Fracturing Technological Efficiency in the Development of Low-Permeability Oil Reservoirs","authors":"Aleksander Valerievich Miroshnichenko, V. Korotovskikh, T. Musabirov, A. Fedorov, Khakim Khalilovich Suleimanov","doi":"10.2118/206412-ms","DOIUrl":"https://doi.org/10.2118/206412-ms","url":null,"abstract":"\u0000 The deterioration of the reservoir properties of potential oil and gas bearing areas on mature and green fields, as well as the increase in the volume of hard-to-recover reserves on low-permeable reservoirs set us new challenges in searching and using effective development technologies to maintain and even increase the oil production levels.\u0000 Based on successful international experience, Russian oil and gas companies use horizontal wells (HW) with multi-stage hydraulic fracturing (MSHF) for the cost-effective development of low-permeable reservoirs. Thus, since the first pilot works of drilling technologies and completion of HW with MSHF in 2011, at the beginning of 2020, over 1,200 HW with MSHF were drilled and came on stream at the fields of LLC RN-Yuganskneftegaz, about half of which are at the exploitation play AS10-12 of the northern license territory (NLT) of the Priobskoye field.\u0000 In searching the best technologies and engineering solutions, the company tested different lengths of horizontal section of HW, the number of hydraulic fracturing (HF) stages and distances between hydraulic fracturing ports, as well as different specific mass of the proppant per frac port. Recently, there has been a tendency in design solutions to increase the length of the HWs and the number of hydraulic fractures with a decreasing distance between the frac ports and a decreasing specific mass of the proppant per frac port.\u0000 This work studies the actual and theoretical efficiency of HW with MSHF of various designs (different lengths of horizontal section of HW and the number of HF stages) and to assess the viability of increasing the technological complexity, as well as to analyze the actual impact of loading the proppant mass per port on performing HW with MSHF. The study is based on the results of the analysis of the factual experience accumulated over the entire history of the development of the exploitation play AS10-12 of the NLT of the Priobskoye field of the Rosneft Company.\u0000 In studying the viability of increasing the technological complexity, especially, increasing the length of horizontal section of HW, increasing the number of HF stages, and reducing the distance between the frac ports:\u0000 we discovered the typical methodological errors made in analyzing the efficiency of wells of various designs; we developed the methodology for analysis of the actual multiplicity of indicators of wells of various designs, in particular, HW with MSHF relative to deviated wells (DW) with HF; we carried out the statistical analysis of the actual values of the multiplicity of performance indicators and completion parameters of HW with MSHF of various designs relative to the surrounding DW with HF of the exploitation play AS10-12 of the NLT of the Priobskoye field; we performed the theoretical calculation of the multiplicity of the productivity coefficient for the HW with MSHF of various designs relative to DW with HF for the standard development system of the exploitati","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"74 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86296090","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 paper considers the choice of the optimal acid treatment technology using chemical flow divertion, for low-temperature heterogeneous and depleted carbonates, based on the analysis of field data, a complex of physico-chemical and core studies. To increase the efficiency of acid treatments of wells that operate the specified reservoir, two technologies of chemical flow divertion (using a gelled acid (GA) and a self-diverting acid (SDA) are considered in the paper. It was revealed that during acid treatments using SDA a longer exposure time of the reagent in the bottom-hole zone (BHZ) of the well is required, as a result of which the planned efficiency for the conditions of the reservoir under consideration is not achieved. By means of core studies, a higher efficiency of using GA under considered conditions was confirmed. The results of physico-chemical and core studies were used to simulate acidizing and adapt treatment designs. Field study of the treatment technology of producing wells with the use of GA was carried out. According to the results of well logging, there is an increase in the working inflow intervals after treatment. The performed field studies confirmed the results of core studies, theoretical studies and physico-chemical surveys.
{"title":"Gelled Acid vs. Self-Diverting Systems for Carbonate Matrix Stimulation: an Experimental and Field Study","authors":"Alexey Evgenievich Folomeev, Ildar Azatovich Taipov, Arslan Rustemovich Khatmullin, Flus Khanifovich Mukhametov, Sergei Alexandrovich Vakhrushev, Fidan Kanafeevich Mingalishev, Vadim Filusovich Abrarov, Alexandr Viktorovich Akimkin","doi":"10.2118/206647-ms","DOIUrl":"https://doi.org/10.2118/206647-ms","url":null,"abstract":"\u0000 The paper considers the choice of the optimal acid treatment technology using chemical flow divertion, for low-temperature heterogeneous and depleted carbonates, based on the analysis of field data, a complex of physico-chemical and core studies. To increase the efficiency of acid treatments of wells that operate the specified reservoir, two technologies of chemical flow divertion (using a gelled acid (GA) and a self-diverting acid (SDA) are considered in the paper.\u0000 It was revealed that during acid treatments using SDA a longer exposure time of the reagent in the bottom-hole zone (BHZ) of the well is required, as a result of which the planned efficiency for the conditions of the reservoir under consideration is not achieved. By means of core studies, a higher efficiency of using GA under considered conditions was confirmed. The results of physico-chemical and core studies were used to simulate acidizing and adapt treatment designs. Field study of the treatment technology of producing wells with the use of GA was carried out. According to the results of well logging, there is an increase in the working inflow intervals after treatment. The performed field studies confirmed the results of core studies, theoretical studies and physico-chemical surveys.","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":"81869057","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}
M. Zhuravlev, Anastasiia Novikova, A. Cherkasova, Dmitry Shakhov, A. Kharkovsky, R. Belousov, Azamat Sadykov, Konstantin Anuchin, Grisha Avanesyan, Vadim Khafizov
The main goal of this paper is to describe the automation process for asset design solutions assessment in accordance with the expected production levels in dynamics. The integrated model contains embedded sub-models (various assessment elements, such as pipeline networks, compression facilities, gas treatment units, reservoir simulation models for production profiles simulation and an economic model to obtain an instant investment estimate). A continuous data flow between all the component models provides a quick assessment of different variables influence on the final efficiency of the integrated asset development option; this approach makes possible the rapid expansion of options range as well as the increase in analysis depth. We describe this approach on the example of the gas assets group development project, which includes the integration of following part of surface facilities: pipeline networks (gathering system) for well pads with the corresponding booster compressor stations and transport network to deliver well product to gas process unit. The work shows the recommendations about how to set up the optimal configuration of an integrated model (type and composition of sub-models, linking algorithms, data exchange directions, etc.) to solve various issues of long-term planning. In addition, we show the example of standardizing the process of managing the sub- models to provide the integrated model fast update when new production data arrives or when the surface facilities concept is changed and to make the approach transfer to other close projects easier. The novelty of the work lies in the creation of a unique approach to solve the issues of conceptual design by flexible configuration of an integrated model for specific tasks. This approach includes processing of production data different formats, the ability to connect an economic model to obtain the instant investment assessment of surface facilities option within comprehensive analysis. In addition, it includes the ability to connect detailed models of the gas-processing unit and booster compressor station with prospective economic efficiency assessment in accordance with the production profiles updates. The integrated model example and overall approach that we provide in this paer is unique due to the following factors: – "flexibility" of the model, which changes its appearance depending on the tasks. – prompt update of the economic indicators of the project. – clear accounting of transport and process facilities (use of detailed models for pipeline and processing systems (including booster compressor stations).
{"title":"Practical Application of Integrated Simulation Technologies for Asset Development and Surface Facilities Design of Gas Fields","authors":"M. Zhuravlev, Anastasiia Novikova, A. Cherkasova, Dmitry Shakhov, A. Kharkovsky, R. Belousov, Azamat Sadykov, Konstantin Anuchin, Grisha Avanesyan, Vadim Khafizov","doi":"10.2118/206551-ms","DOIUrl":"https://doi.org/10.2118/206551-ms","url":null,"abstract":"\u0000 The main goal of this paper is to describe the automation process for asset design solutions assessment in accordance with the expected production levels in dynamics. The integrated model contains embedded sub-models (various assessment elements, such as pipeline networks, compression facilities, gas treatment units, reservoir simulation models for production profiles simulation and an economic model to obtain an instant investment estimate).\u0000 A continuous data flow between all the component models provides a quick assessment of different variables influence on the final efficiency of the integrated asset development option; this approach makes possible the rapid expansion of options range as well as the increase in analysis depth.\u0000 We describe this approach on the example of the gas assets group development project, which includes the integration of following part of surface facilities: pipeline networks (gathering system) for well pads with the corresponding booster compressor stations and transport network to deliver well product to gas process unit. The work shows the recommendations about how to set up the optimal configuration of an integrated model (type and composition of sub-models, linking algorithms, data exchange directions, etc.) to solve various issues of long-term planning. In addition, we show the example of standardizing the process of managing the sub- models to provide the integrated model fast update when new production data arrives or when the surface facilities concept is changed and to make the approach transfer to other close projects easier.\u0000 The novelty of the work lies in the creation of a unique approach to solve the issues of conceptual design by flexible configuration of an integrated model for specific tasks. This approach includes processing of production data different formats, the ability to connect an economic model to obtain the instant investment assessment of surface facilities option within comprehensive analysis. In addition, it includes the ability to connect detailed models of the gas-processing unit and booster compressor station with prospective economic efficiency assessment in accordance with the production profiles updates.\u0000 The integrated model example and overall approach that we provide in this paer is unique due to the following factors:\u0000 – \"flexibility\" of the model, which changes its appearance depending on the tasks. – prompt update of the economic indicators of the project. – clear accounting of transport and process facilities (use of detailed models for pipeline and processing systems (including booster compressor stations).","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"56 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90953907","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}
M. Nukhaev, K. Rymarenko, V. Baranov, S. Grishenko, A. Zaycev, Galymzan Aitkaliev, V. Kabanov, Tatyana Gusachenko, A. Golubtsov
Liquid hydrocarbon production optimization is among key tasks in the gas condensate fields development. It depends on changes in gas supply quotas and on seasonal fluctuations in demand. The key point for such an optimization is the need to understand the current condensate-gas factor (CGF) for each well of the field to select the operating modes. Often, there is no sufficient well surveying data as these surveys are conducted not frequently enough. The paper presents an approach that allows monitoring the CGF for each well in real time and control the operating modes of the wells.
{"title":"The Results of the Implementation of the Technology for Monitoring the Operation of Gas and Gas Condensate Wells According to Condensate to Gas Ratio to Optimize the Production of Liquid Hydrocarbons on the Vostochno-Makarovskoe Field","authors":"M. Nukhaev, K. Rymarenko, V. Baranov, S. Grishenko, A. Zaycev, Galymzan Aitkaliev, V. Kabanov, Tatyana Gusachenko, A. Golubtsov","doi":"10.2118/206579-ms","DOIUrl":"https://doi.org/10.2118/206579-ms","url":null,"abstract":"\u0000 Liquid hydrocarbon production optimization is among key tasks in the gas condensate fields development. It depends on changes in gas supply quotas and on seasonal fluctuations in demand. The key point for such an optimization is the need to understand the current condensate-gas factor (CGF) for each well of the field to select the operating modes. Often, there is no sufficient well surveying data as these surveys are conducted not frequently enough. The paper presents an approach that allows monitoring the CGF for each well in real time and control the operating modes of the wells.","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"20 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"91090877","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}
Artem Galimzyanov, Konstantin Naydensky, O. Huseby
Justified application of enhanced oil recovery (EOR) methods is one of the key tasks of oil operating companies for the effective development of not only brown oil fields at a mature stage of production, but also for green fields. The selection and justification of one or another method of enhanced oil recovery for certain geological conditions often requires not only looking for worldwide experience, conducting laboratory tests on a core, but also performing pilot tests at a polygon area. The subsequent full-field implementation of EOR method requires confirmation of its effectiveness based on the increase in oil recovery factor. This article describes both the experience of using interwell tracer studies to substantiate the effectiveness of EOR technologies in pilot areas, and the experience of evaluating the effectiveness of EOR technologies with full-field implementation in various fields. The work carried out on the integrated use of tracer studies makes it possible to apply a scientific and engineering approach to the selection of an enhanced oil recovery method by assessing the sweep efficiency before and after the application of the EOR technology. Examples of the use of this integrated approach for different oil fields are given. The presented technologies and experience of the work performed will significantly speed up the choice of the EOR technology for certain geological conditions and verify the effectiveness of the selected EOR method.
{"title":"Selection and Justification of Technologies for Enhanced Oil Recovery Methods Using Inter-Well Tracer Survey","authors":"Artem Galimzyanov, Konstantin Naydensky, O. Huseby","doi":"10.2118/206489-ms","DOIUrl":"https://doi.org/10.2118/206489-ms","url":null,"abstract":"\u0000 Justified application of enhanced oil recovery (EOR) methods is one of the key tasks of oil operating companies for the effective development of not only brown oil fields at a mature stage of production, but also for green fields. The selection and justification of one or another method of enhanced oil recovery for certain geological conditions often requires not only looking for worldwide experience, conducting laboratory tests on a core, but also performing pilot tests at a polygon area. The subsequent full-field implementation of EOR method requires confirmation of its effectiveness based on the increase in oil recovery factor.\u0000 This article describes both the experience of using interwell tracer studies to substantiate the effectiveness of EOR technologies in pilot areas, and the experience of evaluating the effectiveness of EOR technologies with full-field implementation in various fields. The work carried out on the integrated use of tracer studies makes it possible to apply a scientific and engineering approach to the selection of an enhanced oil recovery method by assessing the sweep efficiency before and after the application of the EOR technology. Examples of the use of this integrated approach for different oil fields are given.\u0000 The presented technologies and experience of the work performed will significantly speed up the choice of the EOR technology for certain geological conditions and verify the effectiveness of the selected EOR method.","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"14 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82507162","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}
Daniil Yurievich Solovev, Anton Epryntsev, P. I. Eliseev, A. G. Yamov, Yamov Grigorievich Nerodenko, Elkin Bakirovich Guseynov, V. Bobrov
The studied productive formation of gas condensate field is at the stage of declining production. The inflow of bottom water due to the rise of the GWC and the design features of horizontal wells (large tubing and liner diameters) create the prerequisites for the development of a liquid loading of wells. This necessitate the optimization of the existing method of liquid unloading by dosing surfactants into the annulus. In order to increase the efficiency of well treatment with a foaming agent, the use of a surfactant injection system through a capillary string suspended inside a tubing is considered. The use of this system allows to increase the speed and depth of surfactant delivery, use the potential of the well by simultaneous work in tubing and annulus during significant watering period (water flow rate: 50 and more m3 / day), reduce reagent losses associated with retention on the casing walls, and reduce the required consumption of surfactant. The capillary string for the pumping surfactant is applicated to ensuring the stable operation of gas condensate wells during liquid loading. But today there are not ready-made applied solutions for correctly accounting surfactant action in unsteady flows conditions in the well. The paper presents the substantiation and analysis of the capillary string introduction into the well for the pumping surfactant using specialized software. In the course of work, the main analysis tool is the dynamic modeling of multiphase flows in the conditions of steady and unsteady processes in wells. This approach use is aimed at determining the optimal depth and diameter of capillary, the required consumption and concentration of surfactant, the rate of its delivery to the bottomhole, and the liquid removal efficiency from the horizontal wellbore.
{"title":"Adaptation of Capillary String for the Surfactants Delivery into a Gas Condensate Well and Optimization of its Operation Using Dynamic Multiphase Flow Simulator","authors":"Daniil Yurievich Solovev, Anton Epryntsev, P. I. Eliseev, A. G. Yamov, Yamov Grigorievich Nerodenko, Elkin Bakirovich Guseynov, V. Bobrov","doi":"10.2118/206575-ms","DOIUrl":"https://doi.org/10.2118/206575-ms","url":null,"abstract":"\u0000 The studied productive formation of gas condensate field is at the stage of declining production. The inflow of bottom water due to the rise of the GWC and the design features of horizontal wells (large tubing and liner diameters) create the prerequisites for the development of a liquid loading of wells. This necessitate the optimization of the existing method of liquid unloading by dosing surfactants into the annulus.\u0000 In order to increase the efficiency of well treatment with a foaming agent, the use of a surfactant injection system through a capillary string suspended inside a tubing is considered. The use of this system allows to increase the speed and depth of surfactant delivery, use the potential of the well by simultaneous work in tubing and annulus during significant watering period (water flow rate: 50 and more m3 / day), reduce reagent losses associated with retention on the casing walls, and reduce the required consumption of surfactant.\u0000 The capillary string for the pumping surfactant is applicated to ensuring the stable operation of gas condensate wells during liquid loading. But today there are not ready-made applied solutions for correctly accounting surfactant action in unsteady flows conditions in the well.\u0000 The paper presents the substantiation and analysis of the capillary string introduction into the well for the pumping surfactant using specialized software. In the course of work, the main analysis tool is the dynamic modeling of multiphase flows in the conditions of steady and unsteady processes in wells. This approach use is aimed at determining the optimal depth and diameter of capillary, the required consumption and concentration of surfactant, the rate of its delivery to the bottomhole, and the liquid removal efficiency from the horizontal wellbore.","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"195 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83980579","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}
Natural gas hydrate emerges as a sustainable and alternative clean energy source. Japan (2013) and China (2017) have performed production trials on marine natural gas hydrate successfully. Sand production with associated risk is one of the main challenges for offshore natural gas hydrate production trials in Japan and China. Technical assessment related to sand production, transport and erosion is a crucial part for overall sand management strategy. This paper demonstrates the importance of flow assurance for marine natural gas hydrate production through the analysis of sand management in South China Sea ShenHu area. Multiphase modelling tool is used to investigate sand transport phenomenon, with parametric study focuses on the effects of production rates, particle bed height and sand particle size. Detailed analysis of particle flow and related erosion along production flow path is investigated by developing a 3-dimensional Computational Fluids Dynamics (CFD) model. Based on the matrix of sensitivity study, steady state operational map for continuous marine natural gas hydrate production is proposed. Such operational map provides useful risks level ranking based on actual field parameters including gas production rate, sand loading and particle size. The operator can maintain production at a lower risk based on the operational map. Through detailed technical analysis of sand production and transport, risks associated with sand blockage and erosion can be actively managed. This provides high values in terms of operational safety, asset integrity, and full compliance with related national or international HSSE standards.
{"title":"Technical Analysis of Sand Production for Offshore Natural Gas Hydrate Trials in South China Sea","authors":"Kun An, L. Lau, Jian Li, Jia Liu","doi":"10.2118/206411-ms","DOIUrl":"https://doi.org/10.2118/206411-ms","url":null,"abstract":"\u0000 Natural gas hydrate emerges as a sustainable and alternative clean energy source. Japan (2013) and China (2017) have performed production trials on marine natural gas hydrate successfully. Sand production with associated risk is one of the main challenges for offshore natural gas hydrate production trials in Japan and China. Technical assessment related to sand production, transport and erosion is a crucial part for overall sand management strategy.\u0000 This paper demonstrates the importance of flow assurance for marine natural gas hydrate production through the analysis of sand management in South China Sea ShenHu area. Multiphase modelling tool is used to investigate sand transport phenomenon, with parametric study focuses on the effects of production rates, particle bed height and sand particle size. Detailed analysis of particle flow and related erosion along production flow path is investigated by developing a 3-dimensional Computational Fluids Dynamics (CFD) model.\u0000 Based on the matrix of sensitivity study, steady state operational map for continuous marine natural gas hydrate production is proposed. Such operational map provides useful risks level ranking based on actual field parameters including gas production rate, sand loading and particle size. The operator can maintain production at a lower risk based on the operational map.\u0000 Through detailed technical analysis of sand production and transport, risks associated with sand blockage and erosion can be actively managed. This provides high values in terms of operational safety, asset integrity, and full compliance with related national or international HSSE standards.","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"55 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89188145","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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