S. Novikov, M. Charupa, Yakov Dzhalatyan, Stanislav Sergeevich Kuzmin, Y. Kaipov, Eduard Yurevich Kazakevich, Yuri Nikolaevich Smetanin, A. Kishauov, A. Snokhin, Oleg Raisovich Ibragimov
As the production of oil and gas in major regions has been declining, exploration efforts are shifting towards hard-to-reach understudied areas with lack of necessary infrastructure. In addition to that, hydrocarbon fields that are being explored today, typically have more complex geological structure than the ones discovered decades ago and are characterized by the presence of multiple reservoirs with individual fluid contacts. The abovementioned reasons cause significant increase in time required to test these reservoirs and estimate their production potential. Therefore, there is a real need for reliable technologies that would expedite the testing of such complex fields. New wireline formation testing platform has an updated hardware architecture enabling to use it for both traditional formations testing applications as well as the development of new testing procedures deviating from conventional practices. This paper describes the novel testing approach implying the use of wireline formation tester (WFT) in conjunction with a surface multiphase flowmeter, which was implemented at one of the large gas fields located on the Gydan peninsula. A key feature of the new formation testing platform compared to its predecessors is its ability to pump an order of magnitude greater volumes of reservoir fluids, which allows to estimate permeability in the uninvaded zone of the reservoirs and their productivity. Combination of the wireline formation tester with the surface multiphase flowmeter enables measuring surface rates and capture surface samples of reservoir fluids thus making this type of testing comparable to traditional well testing. At the beginning of the paper we provide a brief description of the acquired formation testing results with stress on key features of the new wireline formation testing platform. The rest of the paper is devoted to Deep Transient Testing (DTT), more specifically, to its design and planning, required hardware and description of results acquired during such tests. We also demonstrate an approach that can be used to estimate reservoir productivity based on the obtained data.
{"title":"New Generation of Formation Testers – New Horizons: First Experience in Russia","authors":"S. Novikov, M. Charupa, Yakov Dzhalatyan, Stanislav Sergeevich Kuzmin, Y. Kaipov, Eduard Yurevich Kazakevich, Yuri Nikolaevich Smetanin, A. Kishauov, A. Snokhin, Oleg Raisovich Ibragimov","doi":"10.2118/206491-ms","DOIUrl":"https://doi.org/10.2118/206491-ms","url":null,"abstract":"\u0000 As the production of oil and gas in major regions has been declining, exploration efforts are shifting towards hard-to-reach understudied areas with lack of necessary infrastructure. In addition to that, hydrocarbon fields that are being explored today, typically have more complex geological structure than the ones discovered decades ago and are characterized by the presence of multiple reservoirs with individual fluid contacts. The abovementioned reasons cause significant increase in time required to test these reservoirs and estimate their production potential. Therefore, there is a real need for reliable technologies that would expedite the testing of such complex fields.\u0000 New wireline formation testing platform has an updated hardware architecture enabling to use it for both traditional formations testing applications as well as the development of new testing procedures deviating from conventional practices. This paper describes the novel testing approach implying the use of wireline formation tester (WFT) in conjunction with a surface multiphase flowmeter, which was implemented at one of the large gas fields located on the Gydan peninsula. A key feature of the new formation testing platform compared to its predecessors is its ability to pump an order of magnitude greater volumes of reservoir fluids, which allows to estimate permeability in the uninvaded zone of the reservoirs and their productivity. Combination of the wireline formation tester with the surface multiphase flowmeter enables measuring surface rates and capture surface samples of reservoir fluids thus making this type of testing comparable to traditional well testing.\u0000 At the beginning of the paper we provide a brief description of the acquired formation testing results with stress on key features of the new wireline formation testing platform. The rest of the paper is devoted to Deep Transient Testing (DTT), more specifically, to its design and planning, required hardware and description of results acquired during such tests. We also demonstrate an approach that can be used to estimate reservoir productivity based on the obtained data.","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"61 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76116286","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}
This manuscript describes the approach in the risk management developed and implemented while operating 21 drilling rigs on 13 fields simultaneously in the Middle East, which resulted in 40% reduction of non-productive time. Well construction process requires a lot of attention on different levels and from different sides to ensure trouble-free execution. The bigger the volume of work, the higher the chance of a costly mistake. The risk management process was split in several steps, where different levels and divisions are involved. The Planning stage starts at engineering level and associated risk review goes to a level of Division Supervisor for every well, when special tools were developed to focus on potential high impact events. The Execution stage was covered by a set of Critical Activity reviews and Standard operation procedures, focusing on operations with highest risks or highest benefits. Further at the Evaluation stage every well was analyzed following the developed workflow, and further all obtained knowledge shared with every team member via custom designed dashboards. Shortly after initial steps were taken under the new risk management approach, one of main KPI – non-productive time (NPT) – started to decrease and dropped by 5% within one quarter. Further tuning of the process allowed to decrease NPT by over 40% with continuous positive trend. One of the main contributors is the re-focusing on the prevention measures during planning stage, which avoid non-conformance events with high impact. Simultaneously the approach unified the practices of different divisions and remove misalignment on most of the technical issues and questions. Additionally, it decreased the workload of the key field personnel, as reduced NPT gives more time to focus on continuous rig performance improvement.
{"title":"Risk Management Approach: Drilling and Completion Projects","authors":"A. Ruzhnikov, Viktor Yurtaev","doi":"10.2118/206565-ms","DOIUrl":"https://doi.org/10.2118/206565-ms","url":null,"abstract":"\u0000 This manuscript describes the approach in the risk management developed and implemented while operating 21 drilling rigs on 13 fields simultaneously in the Middle East, which resulted in 40% reduction of non-productive time. Well construction process requires a lot of attention on different levels and from different sides to ensure trouble-free execution. The bigger the volume of work, the higher the chance of a costly mistake.\u0000 The risk management process was split in several steps, where different levels and divisions are involved. The Planning stage starts at engineering level and associated risk review goes to a level of Division Supervisor for every well, when special tools were developed to focus on potential high impact events. The Execution stage was covered by a set of Critical Activity reviews and Standard operation procedures, focusing on operations with highest risks or highest benefits. Further at the Evaluation stage every well was analyzed following the developed workflow, and further all obtained knowledge shared with every team member via custom designed dashboards.\u0000 Shortly after initial steps were taken under the new risk management approach, one of main KPI – non-productive time (NPT) – started to decrease and dropped by 5% within one quarter. Further tuning of the process allowed to decrease NPT by over 40% with continuous positive trend. One of the main contributors is the re-focusing on the prevention measures during planning stage, which avoid non-conformance events with high impact. Simultaneously the approach unified the practices of different divisions and remove misalignment on most of the technical issues and questions. Additionally, it decreased the workload of the key field personnel, as reduced NPT gives more time to focus on continuous rig performance improvement.","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"100 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79343142","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}
Today, strategic planning of field development is based on full-field static and flow simulation models which are regularly updated as part of field surveillance programs and by integrating the actual results of drilling and testing of new production and exploration wells and integrated interpretation of seismic surveys and reservoir core and fluid laboratory analyses. One of the key factors for the success of investment projects is how quick and flexible the decision-making process is. Therefore, in modern conditions, prompt integration of new data into full-field flow simulation models followed by their processing, analysis, and decision-making on adjusting the strategic goals is of particular relevance for oil and gas production companies. For unique multi-reservoir fields containing dozens of reservoirs, hundreds of accumulations and wells, it is hardly possible to promptly update full-field static and flow simulation models within less than 6-12 months, therefore, the decisions are made in the absence of up-to-date models, which may lead to poor quality of production forecasts. The purpose of the study was to develop an approach to the modeling of unique fields, which would allow prompt integration of new data in a full-field flow simulation model while keeping the level of detail without significant time input.
{"title":"Solving the Problem of Operational Accounting of Well Drilling Results in a Full-Scale Model of Unique Gas Condensate Fields","authors":"A. Poushev, R. R. Mangushev, S. Yakimov","doi":"10.2118/206583-ms","DOIUrl":"https://doi.org/10.2118/206583-ms","url":null,"abstract":"\u0000 Today, strategic planning of field development is based on full-field static and flow simulation models which are regularly updated as part of field surveillance programs and by integrating the actual results of drilling and testing of new production and exploration wells and integrated interpretation of seismic surveys and reservoir core and fluid laboratory analyses.\u0000 One of the key factors for the success of investment projects is how quick and flexible the decision-making process is. Therefore, in modern conditions, prompt integration of new data into full-field flow simulation models followed by their processing, analysis, and decision-making on adjusting the strategic goals is of particular relevance for oil and gas production companies.\u0000 For unique multi-reservoir fields containing dozens of reservoirs, hundreds of accumulations and wells, it is hardly possible to promptly update full-field static and flow simulation models within less than 6-12 months, therefore, the decisions are made in the absence of up-to-date models, which may lead to poor quality of production forecasts.\u0000 The purpose of the study was to develop an approach to the modeling of unique fields, which would allow prompt integration of new data in a full-field flow simulation model while keeping the level of detail without significant time input.","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"15 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81887619","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}
S. Melnikov, N. Vershigora, Alexander Alexandrovich Groo, D. Grigorev, Pavel Yurievich Kiselev, V. Morozov
A decision to buy oil and gas assets requires a project evaluation (PE) aimed at integrated calculation of numerous possible scenarios of asset development, based on the uncertain resource values, variety of geological exploration program events, the most preferable decisions about the oil field development in the current economic conditions. The vast amount of calculations determined by the probabilistic nature of the PE and specific timeframes require optimization of the current approaches based on the balance between accuracy and time. This issue is particularly relevant for the evaluation and analysis of gas or gas-condensate field cluster as the profitability of the project can be concentrated in the asset integration into one production cluster. Such option as well as proposal to gather separate fields to the common infrastructure, sequence of fields development with different geological and physical characteristics, calculations of a large number of synergy options, etc. require the multi-disciplinary team to think outside the box while searching for a business case. Thus, this paper is aimed to improve current approaches and the current tools adaptation which will be used to drastically automate cross-functional probability estimate of gas field cluster with technical and economic justification of sustainable integrated solutions. The results were successfully validated within PE of several perspective gas condensate projects focused on the possibility of integration of the fields into a single cluster that creates additional value from the optimization of the project solutions (exploration, development strategy, gathering and transportation of hydrocarbons, monetization of the products) equal to tens of billions of rubles in a limited period of time.
{"title":"An Improved Methodology for Gas-Condensate Cluster Evaluations under Uncertainty","authors":"S. Melnikov, N. Vershigora, Alexander Alexandrovich Groo, D. Grigorev, Pavel Yurievich Kiselev, V. Morozov","doi":"10.2118/206572-ms","DOIUrl":"https://doi.org/10.2118/206572-ms","url":null,"abstract":"\u0000 A decision to buy oil and gas assets requires a project evaluation (PE) aimed at integrated calculation of numerous possible scenarios of asset development, based on the uncertain resource values, variety of geological exploration program events, the most preferable decisions about the oil field development in the current economic conditions.\u0000 The vast amount of calculations determined by the probabilistic nature of the PE and specific timeframes require optimization of the current approaches based on the balance between accuracy and time. This issue is particularly relevant for the evaluation and analysis of gas or gas-condensate field cluster as the profitability of the project can be concentrated in the asset integration into one production cluster. Such option as well as proposal to gather separate fields to the common infrastructure, sequence of fields development with different geological and physical characteristics, calculations of a large number of synergy options, etc. require the multi-disciplinary team to think outside the box while searching for a business case. Thus, this paper is aimed to improve current approaches and the current tools adaptation which will be used to drastically automate cross-functional probability estimate of gas field cluster with technical and economic justification of sustainable integrated solutions.\u0000 The results were successfully validated within PE of several perspective gas condensate projects focused on the possibility of integration of the fields into a single cluster that creates additional value from the optimization of the project solutions (exploration, development strategy, gathering and transportation of hydrocarbons, monetization of the products) equal to tens of billions of rubles in a limited period of time.","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":"85852777","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}
Diana Amangeldiyeva, A. Aliyeva, Yerlan Amanbayev, J. S. Toralde, Tim Higginson, Akzharkyn Assetkyzy Tilekkabyl, Dinmukhamed Jangaliuly Nurseiitov, Yong Fan, Gareth Cameron
This paper describes the development and field deployment of a new downhole isolation valve system called the Retrievable, Instrumented & Tandem Downhole Deployment Valve (RIT-DDV). The purpose of this technology is to provide a temporary mechanical barrier to isolate and monitor the well during drilling operations in an environment where a full column of single-phase fluid cannot be maintained. The RIT-DDV is based on predominantly used downhole isolation valve (DIV) design and technology, which is a hydraulic flapper-type isolation device installed in the casing that seals the open hole during pipe tripping operations. The key features of the new RIT-DDV systems are dual flapper valves with three downhole pressure and temperature gauges to take measurements above, between, and below the flappers. The advantage of this configuration is that it enhances safety by enabling double-block-and-bleed system functionality, providing valve redundancy, and moreover allowing for continuous real-time monitoring of downhole well conditions. In addition, the RIT-DDV is designed to be reusable and can be tested upon installation and replaced if necessary. The RIT-DDV system enabled the operator to isolate and monitor the well while drilling through a depleted formation that prevented drilling with a full column of single-phase drilling fluid. The RIT-DDV was successfully trialed in western Kazakhstan and demonstrated the potential of this technology to enhance the safety of drilling heavily fractured carbonate formations with reservoir fluids containing hydrogen sulfide (H2S) / carbon dioxide (CO2) that are prone to total loss of circulation. The downhole pressure / temperature monitoring capabilities that the system provides within the casing string helped drill through the depleted fractured carbonate reservoir section without incurring non-productive time (NPT).
{"title":"Development and Successful Field Trial of Retrievable, Instrumented & Tandem Downhole Isolation Valve RIT-DIV System","authors":"Diana Amangeldiyeva, A. Aliyeva, Yerlan Amanbayev, J. S. Toralde, Tim Higginson, Akzharkyn Assetkyzy Tilekkabyl, Dinmukhamed Jangaliuly Nurseiitov, Yong Fan, Gareth Cameron","doi":"10.2118/206440-ms","DOIUrl":"https://doi.org/10.2118/206440-ms","url":null,"abstract":"\u0000 This paper describes the development and field deployment of a new downhole isolation valve system called the Retrievable, Instrumented & Tandem Downhole Deployment Valve (RIT-DDV). The purpose of this technology is to provide a temporary mechanical barrier to isolate and monitor the well during drilling operations in an environment where a full column of single-phase fluid cannot be maintained.\u0000 The RIT-DDV is based on predominantly used downhole isolation valve (DIV) design and technology, which is a hydraulic flapper-type isolation device installed in the casing that seals the open hole during pipe tripping operations.\u0000 The key features of the new RIT-DDV systems are dual flapper valves with three downhole pressure and temperature gauges to take measurements above, between, and below the flappers. The advantage of this configuration is that it enhances safety by enabling double-block-and-bleed system functionality, providing valve redundancy, and moreover allowing for continuous real-time monitoring of downhole well conditions. In addition, the RIT-DDV is designed to be reusable and can be tested upon installation and replaced if necessary. The RIT-DDV system enabled the operator to isolate and monitor the well while drilling through a depleted formation that prevented drilling with a full column of single-phase drilling fluid. The RIT-DDV was successfully trialed in western Kazakhstan and demonstrated the potential of this technology to enhance the safety of drilling heavily fractured carbonate formations with reservoir fluids containing hydrogen sulfide (H2S) / carbon dioxide (CO2) that are prone to total loss of circulation. The downhole pressure / temperature monitoring capabilities that the system provides within the casing string helped drill through the depleted fractured carbonate reservoir section without incurring non-productive time (NPT).","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"48 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85442309","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}
Anton Yurievich Gavrilov, A. A. Bandaletova, Natalia A. Devleshova, Evgeny Vladimirovich Galin, M. Pisarev, Dmitry Alexandrovich Liss
Current production conditions and development of oil fields are complicated by the development of increasingly difficult-to-recover reserves as well as by the consequences of 2020, which include a change in the structure of demand and a collapse of the oil market, the global trend towards low-carb fuel systems and the implementation of the principles of environmental, social and managerial responsibility (ESG). This research paper is focused on diversification of the oil and gas business by extracting lithium from reservoir waters of oil and gas condensate fields. This method allows to increase the profitability of deposits. The paper also carries out a technical and economic assessment of the process of the sorption lithium extraction from the formation waters of oil fields.
{"title":"Recovery of Lithium from Associated Water of Oil and Gas Deposits","authors":"Anton Yurievich Gavrilov, A. A. Bandaletova, Natalia A. Devleshova, Evgeny Vladimirovich Galin, M. Pisarev, Dmitry Alexandrovich Liss","doi":"10.2118/206571-ms","DOIUrl":"https://doi.org/10.2118/206571-ms","url":null,"abstract":"\u0000 Current production conditions and development of oil fields are complicated by the development of increasingly difficult-to-recover reserves as well as by the consequences of 2020, which include a change in the structure of demand and a collapse of the oil market, the global trend towards low-carb fuel systems and the implementation of the principles of environmental, social and managerial responsibility (ESG).\u0000 This research paper is focused on diversification of the oil and gas business by extracting lithium from reservoir waters of oil and gas condensate fields. This method allows to increase the profitability of deposits. The paper also carries out a technical and economic assessment of the process of the sorption lithium extraction from the formation waters of oil fields.","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"85 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90717515","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}
Bulat Magizov, D. Molchanov, Alisa Devyashina, T. Topalova, Ksenya Zinchenko, Alexander Kovalenko
More and more oil and gas fields are moving into the third stage of development - the stage of production decline. Oil and gas operating companies are looking for the most effective ways of production stabilization and extending the period of well exploitation. The most frequently used approach of improving exhausted reservoirs performance is reducing the pace of pressure and hydrocarbons production decline by well workovers and horizontal sidetracks drilling. The most widely used type of new producing wells trajectory in low - and medium-amplitude gas fields, which include most of the Western Siberia gas reserves, is horizontal completion. According to the analysis carried out by two major Rosneft scientific centers, in oil saturated reservoirs with thickness less than 20 meters, the efficiency of horizontal wells with 300 meters length is 1.6-4 times higher than for directional wells, depending on the reservoir thickness and permeability. In gas saturated formations, the efficiency of horizontal wells performance relative to the directionally drilled wells in similar geological conditions is 3-6 times higher. As the consequence of scientifically based well performance analysis the volume of horizontal wells drilling and horizontal side track completions at the assets of PJSC "NK "Rosneft" significanty increased as for the period from 2016 to 2021, Figure 1.
{"title":"Multivariant Well Placement and Well Drilling Parameters Optimization Methodology. Case Study from Yamal Gas Field","authors":"Bulat Magizov, D. Molchanov, Alisa Devyashina, T. Topalova, Ksenya Zinchenko, Alexander Kovalenko","doi":"10.2118/206574-ms","DOIUrl":"https://doi.org/10.2118/206574-ms","url":null,"abstract":"\u0000 More and more oil and gas fields are moving into the third stage of development - the stage of production decline. Oil and gas operating companies are looking for the most effective ways of production stabilization and extending the period of well exploitation. The most frequently used approach of improving exhausted reservoirs performance is reducing the pace of pressure and hydrocarbons production decline by well workovers and horizontal sidetracks drilling.\u0000 The most widely used type of new producing wells trajectory in low - and medium-amplitude gas fields, which include most of the Western Siberia gas reserves, is horizontal completion. According to the analysis carried out by two major Rosneft scientific centers, in oil saturated reservoirs with thickness less than 20 meters, the efficiency of horizontal wells with 300 meters length is 1.6-4 times higher than for directional wells, depending on the reservoir thickness and permeability. In gas saturated formations, the efficiency of horizontal wells performance relative to the directionally drilled wells in similar geological conditions is 3-6 times higher.\u0000 As the consequence of scientifically based well performance analysis the volume of horizontal wells drilling and horizontal side track completions at the assets of PJSC \"NK \"Rosneft\" significanty increased as for the period from 2016 to 2021, Figure 1.","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"62 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"91266242","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}
Aleksei Anatolyevich Gorlanov, Dmitrii Yurevich Vorontsov, Aleksei Sergeevich Schetinin, A. I. Aksenov, Diana Gennadyevna Ovchinnikova
In the process of developing massive gas reservoirs, gas-water contact (GWC) rise is inevitable, which leads to water-breakthrough in wells and declining daily gas production. Drilling horizontal sidetracks and new horizontal wells helps to maintain target production levels. The direction of drilling a horizontal well section largely determines its efficiency. In complex geological conditions, a detailed analysis of seismic data in the drilling area helps to reduce drilling risks and achieve planned starting parameters. The integration of seismic data in geological models is often limited by poor correlation between reservoir properties from wells and seismic attributes. Flow simulation models use seismic data based on the assumptions made by the geological engineers. The study uses a cyclic approach to geological modeling: realizations include in-depth analysis of seismic data and well performance profiles. Modern software modules were used to automatically check the compliance of the geological realization with the development history, as well as to assess the uncertainties. This made it possible to obtain good correlation between well water cut and seismic attributes and to develop a method for determining the presence of shale barriers and "merging windows" of a massive gas reservoir with water-saturated volumes.
{"title":"Seismic Data Analysis for Well Performance and Production Data Forecast: Massive Low-Relief Gas Reservoir Case Study","authors":"Aleksei Anatolyevich Gorlanov, Dmitrii Yurevich Vorontsov, Aleksei Sergeevich Schetinin, A. I. Aksenov, Diana Gennadyevna Ovchinnikova","doi":"10.2118/206548-ms","DOIUrl":"https://doi.org/10.2118/206548-ms","url":null,"abstract":"\u0000 In the process of developing massive gas reservoirs, gas-water contact (GWC) rise is inevitable, which leads to water-breakthrough in wells and declining daily gas production. Drilling horizontal sidetracks and new horizontal wells helps to maintain target production levels.\u0000 The direction of drilling a horizontal well section largely determines its efficiency. In complex geological conditions, a detailed analysis of seismic data in the drilling area helps to reduce drilling risks and achieve planned starting parameters.\u0000 The integration of seismic data in geological models is often limited by poor correlation between reservoir properties from wells and seismic attributes. Flow simulation models use seismic data based on the assumptions made by the geological engineers.\u0000 The study uses a cyclic approach to geological modeling: realizations include in-depth analysis of seismic data and well performance profiles. Modern software modules were used to automatically check the compliance of the geological realization with the development history, as well as to assess the uncertainties. This made it possible to obtain good correlation between well water cut and seismic attributes and to develop a method for determining the presence of shale barriers and \"merging windows\" of a massive gas reservoir with water-saturated volumes.","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"132 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79122363","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}
R. Apasov, I. V. Perevozkin, R. Badgutdinov, Dmitriy Yurievich Bazhenov, S. Nekhaev, A. Varavva, F. A. Koryakin, D. Samolovov, Ekaterina Evgenievna Sandalova, A. Yamaletdinov
The request for optimization of development system parameters, well designs and the ground facility architecture is permanent task during the development of hydrocarbon fields. Decrease in the quality of oil and gas reserves, development of fields in difficult environment conditions and in the Arctic, oil and gas prices development lead to an increase in the sensitivity of new field’s development profitability from the parameters of the development system and field facilities. Infrastructure of a field for the development of a gas field is associated with significant capital costs, both for the construction of wells and local infrastructure facilities, and for the construction of facilities for the preparation and transportation of gas. Therefore, one of the main tasks in the design of gas field development is the calculation of the optimal parameters of the development system - the number of wells and gas production plateau. Now the most well-known approaches to solving this problem are the calculation of different development variants using integrated numerical hydrodynamic models (Apasov et.al., 2018), taking into account all the features of the field under consideration or using analytical models based on the fundamental principles of filtration theory and development experience. In such conditions, when solving optimization problems, it is necessary to take into account all the components of the production system (Khasanov et.al., 2020), otherwise it can be an incorrectly assessment of the economic effect of optimization and face the unprofitability of the developed design solutions. For most oil fields, the interinfluence of the reservoir part of the field, well lifts and the infrastructure is relatively weak, therefore, these parts can be optimized separately. When designing the development of fields with oil rims and gas fields, especially multilayer ones, optimization requires searching for a global optimal solution, investigating the existence and uniqueness of such a solution - on the models describing the field and interaction of the infrastructure, well lifts and the reservior part.
{"title":"Method for Determine Optimal Parameters of Gas Field Development System","authors":"R. Apasov, I. V. Perevozkin, R. Badgutdinov, Dmitriy Yurievich Bazhenov, S. Nekhaev, A. Varavva, F. A. Koryakin, D. Samolovov, Ekaterina Evgenievna Sandalova, A. Yamaletdinov","doi":"10.2118/206576-ms","DOIUrl":"https://doi.org/10.2118/206576-ms","url":null,"abstract":"\u0000 The request for optimization of development system parameters, well designs and the ground facility architecture is permanent task during the development of hydrocarbon fields. Decrease in the quality of oil and gas reserves, development of fields in difficult environment conditions and in the Arctic, oil and gas prices development lead to an increase in the sensitivity of new field’s development profitability from the parameters of the development system and field facilities.\u0000 Infrastructure of a field for the development of a gas field is associated with significant capital costs, both for the construction of wells and local infrastructure facilities, and for the construction of facilities for the preparation and transportation of gas. Therefore, one of the main tasks in the design of gas field development is the calculation of the optimal parameters of the development system - the number of wells and gas production plateau. Now the most well-known approaches to solving this problem are the calculation of different development variants using integrated numerical hydrodynamic models (Apasov et.al., 2018), taking into account all the features of the field under consideration or using analytical models based on the fundamental principles of filtration theory and development experience.\u0000 In such conditions, when solving optimization problems, it is necessary to take into account all the components of the production system (Khasanov et.al., 2020), otherwise it can be an incorrectly assessment of the economic effect of optimization and face the unprofitability of the developed design solutions. For most oil fields, the interinfluence of the reservoir part of the field, well lifts and the infrastructure is relatively weak, therefore, these parts can be optimized separately. When designing the development of fields with oil rims and gas fields, especially multilayer ones, optimization requires searching for a global optimal solution, investigating the existence and uniqueness of such a solution - on the models describing the field and interaction of the infrastructure, well lifts and the reservior part.","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":"84414932","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 Blyablyas, S. Vershinin, Petr Nikolaevich Afanasiev, A. Mingazov, R. F. Akhmetgareev
As geological environment becomes more complicated, specifics of oil fields with high gas content more demanding, and the Company's requirements for assets development efficiency more stringent, new challenges arise that require application of high-tech approaches and new tools to solve the tasks set. The era of "easy" oil is far behind, and there are no "simple" tasks left, so the key goal of oil companies now is to radically improve efficiency of existing "difficult" fields including development of gas condensate reservoirs and oil rims. The interest in development of new approaches to improve efficiency of the Novoportovskoye field is caused by the huge potential of the asset. Despite the fact that the field was discovered back in 1964, its remaining reserves are estimated at more than 250 million tons of oil and gas condensate and more than 270 billion cubic meters of natural gas, which are concentrated in five reservoirs. The Novoportovskoye field is the northernmost and largest on the Yamal Peninsula, but the complexity of its development and operation is caused not so much by geography and the lack of transport infrastructure but by the presence of a gas cap, low reservoir permeability, the occurrence of underlying water, and high gas content in produced reservoir fluid. The high gas content complicates the production process. The main method of operation in the existing fields of the Yamal Peninsula is artificial lift by electric submersible pumps (ESP) on rental basis. Given the remoteness and isolation of the Arctic region, the high cost of equipment rental, and the low efficiency of ESPs in liquids with high content of dissolved gas, it is only fair to ask a question of whether there is a tool that may allow us to predict operation parameters for different lift methods. The existing models and tools intended to assess behavior of the field are not good enough to fully predict gas breakthrough rates, optimize well operation parameters in case of short-term production forecasting, or select the optimal lift method. In this paper, we described application of an integrated modeling process for a targeted assessment of well operation parameters at the Novoportovskoye field. Also, in the framework of this paper, we performed a technical and economic estimation of the options under consideration, and formulated some recommendations to improve efficiency of development and operation of the field under the impact of the existing complicating factors.
{"title":"Comprehensive Assessment and Targeted Approach to the Implementation of the Gas-Lift Method of Operation on the Yamal Peninsula Novy Port Field","authors":"Aleksander Blyablyas, S. Vershinin, Petr Nikolaevich Afanasiev, A. Mingazov, R. F. Akhmetgareev","doi":"10.2118/206569-ms","DOIUrl":"https://doi.org/10.2118/206569-ms","url":null,"abstract":"\u0000 As geological environment becomes more complicated, specifics of oil fields with high gas content more demanding, and the Company's requirements for assets development efficiency more stringent, new challenges arise that require application of high-tech approaches and new tools to solve the tasks set. The era of \"easy\" oil is far behind, and there are no \"simple\" tasks left, so the key goal of oil companies now is to radically improve efficiency of existing \"difficult\" fields including development of gas condensate reservoirs and oil rims.\u0000 The interest in development of new approaches to improve efficiency of the Novoportovskoye field is caused by the huge potential of the asset. Despite the fact that the field was discovered back in 1964, its remaining reserves are estimated at more than 250 million tons of oil and gas condensate and more than 270 billion cubic meters of natural gas, which are concentrated in five reservoirs. The Novoportovskoye field is the northernmost and largest on the Yamal Peninsula, but the complexity of its development and operation is caused not so much by geography and the lack of transport infrastructure but by the presence of a gas cap, low reservoir permeability, the occurrence of underlying water, and high gas content in produced reservoir fluid.\u0000 The high gas content complicates the production process. The main method of operation in the existing fields of the Yamal Peninsula is artificial lift by electric submersible pumps (ESP) on rental basis. Given the remoteness and isolation of the Arctic region, the high cost of equipment rental, and the low efficiency of ESPs in liquids with high content of dissolved gas, it is only fair to ask a question of whether there is a tool that may allow us to predict operation parameters for different lift methods.\u0000 The existing models and tools intended to assess behavior of the field are not good enough to fully predict gas breakthrough rates, optimize well operation parameters in case of short-term production forecasting, or select the optimal lift method.\u0000 In this paper, we described application of an integrated modeling process for a targeted assessment of well operation parameters at the Novoportovskoye field. Also, in the framework of this paper, we performed a technical and economic estimation of the options under consideration, and formulated some recommendations to improve efficiency of development and operation of the field under the impact of the existing complicating factors.","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"75 9 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85948634","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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