D. Chaplygin, D. Khamadaliev, A. Sednev, Dmitry Naimushin
One of the main objectives for the successful development of the majority of producing oil and gas companies in western Siberia is the development of the Achimov strata. It contains a commercially attractive volume of reserves. This reservoir in most oilfields belongs to the hard-to-recover oil - it has a permeability of less than 2 mD. In this regard, the development of the Achimov strata is impossible without carrying out measures for production enhancement. Where most common is hydraulic fracturing. The wells tests with hydraulic fracturing conducted at the Salym group of fields showed that not all reserves are economically attractive, and the decline rate in the first year is extremely high. In this connection, the needs of finding more effective solutions for the production enhancement has become urgent. This article describes the results of pilot work on two wells using a mixture based on a high-viscosity friction reducer (HVFR) as the hydraulic fracturing fluid. The work was carried out at wells where hydraulic fracturing based on cross-linked gel had already been performed and the wells were launched into production. The results of the work, the lessons learned and the analysis of the subsequent production of these wells is the purpose of this work.
{"title":"Case Studies of Re-Fracturing Achimov Reservoirs with High-Viscous Friction Reducer on Salym Group of Oilfields","authors":"D. Chaplygin, D. Khamadaliev, A. Sednev, Dmitry Naimushin","doi":"10.2118/206650-ms","DOIUrl":"https://doi.org/10.2118/206650-ms","url":null,"abstract":"\u0000 One of the main objectives for the successful development of the majority of producing oil and gas companies in western Siberia is the development of the Achimov strata. It contains a commercially attractive volume of reserves. This reservoir in most oilfields belongs to the hard-to-recover oil - it has a permeability of less than 2 mD. In this regard, the development of the Achimov strata is impossible without carrying out measures for production enhancement. Where most common is hydraulic fracturing.\u0000 The wells tests with hydraulic fracturing conducted at the Salym group of fields showed that not all reserves are economically attractive, and the decline rate in the first year is extremely high. In this connection, the needs of finding more effective solutions for the production enhancement has become urgent.\u0000 This article describes the results of pilot work on two wells using a mixture based on a high-viscosity friction reducer (HVFR) as the hydraulic fracturing fluid. The work was carried out at wells where hydraulic fracturing based on cross-linked gel had already been performed and the wells were launched into production.\u0000 The results of the work, the lessons learned and the analysis of the subsequent production of these wells is the purpose of this work.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"19 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83096392","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}
N. Cheremisin, R. Shulga, A. Zagorovskiy, Y. Gilmanov, Alexey Valentinovich Kochetov
The laboratory study of the formation of residual oil saturation in a gas cap after active gas production from it and the penetration of oil from the underlying oil reservoir is currently not regulated in any way. Residual oil saturation in the gas cap was taken and is accepted, as a rule, from the correlation dependences with reservoir properties obtained from experiments on oil displacement from to the limit oil-saturated core samples. The use of similar correlations for the transition zone significantly underestimates the mobile oil reserves in such zones In this connection, the paper discusses the technology of physical modeling of the residual oil saturation in the gas cap after the penetration of oil into it and the issues related to the determination of the residual oil saturation in the transition zones of oil reservoirs. On a series of test experiments on core samples of a weakly consolidated reservoir of the Pokurovskaya formation carried out according to the method developed by the authors, it was shown that the values of residual oil saturation after the penetration of oil into the gas cap are significantly lower than for oil-saturated formations with similar properties. It is shown that such studies will make it possible to clarify the possible irreversible oil losses during the advanced development of gas caps and to revise the approaches to the development of oil reservoirs of gas-oil and oil-gas fields. Laboratory modeling and study of the process of oil penetration into a gas cap and its subsequent displacement by water or gas is relevant for almost 10% of Rosneft's current reserves.
{"title":"Residual Hydrocarbon Saturation in the Transition Zone and the Gas Cap","authors":"N. Cheremisin, R. Shulga, A. Zagorovskiy, Y. Gilmanov, Alexey Valentinovich Kochetov","doi":"10.2118/206585-ms","DOIUrl":"https://doi.org/10.2118/206585-ms","url":null,"abstract":"\u0000 The laboratory study of the formation of residual oil saturation in a gas cap after active gas production from it and the penetration of oil from the underlying oil reservoir is currently not regulated in any way. Residual oil saturation in the gas cap was taken and is accepted, as a rule, from the correlation dependences with reservoir properties obtained from experiments on oil displacement from to the limit oil-saturated core samples. The use of similar correlations for the transition zone significantly underestimates the mobile oil reserves in such zones\u0000 In this connection, the paper discusses the technology of physical modeling of the residual oil saturation in the gas cap after the penetration of oil into it and the issues related to the determination of the residual oil saturation in the transition zones of oil reservoirs. On a series of test experiments on core samples of a weakly consolidated reservoir of the Pokurovskaya formation carried out according to the method developed by the authors, it was shown that the values of residual oil saturation after the penetration of oil into the gas cap are significantly lower than for oil-saturated formations with similar properties.\u0000 It is shown that such studies will make it possible to clarify the possible irreversible oil losses during the advanced development of gas caps and to revise the approaches to the development of oil reservoirs of gas-oil and oil-gas fields. Laboratory modeling and study of the process of oil penetration into a gas cap and its subsequent displacement by water or gas is relevant for almost 10% of Rosneft's current reserves.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"29 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88525698","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. V. Kazak, S. Panin, Andrei Mikhailovich Valenkov, Tsimur Donalovich Hiliazitdzinau
This work studies the rheological properties of aqueous solutions of acrylamide copolymers. The prevailing role of elastic properties over viscous properties in predicting the proppant suspension capacity of the resulting fracturing fluid is shown. Furthermore, the potential of the use of oscillatory rheometry for studying fracturing fluid stability is demonstrated.
{"title":"Development of Fracturing Fluids Based on Acrylamide Copolymers and Study of Their Physical and Technological Properties Using the Oscillatory Rheometry Methods","authors":"M. V. Kazak, S. Panin, Andrei Mikhailovich Valenkov, Tsimur Donalovich Hiliazitdzinau","doi":"10.2118/206638-ms","DOIUrl":"https://doi.org/10.2118/206638-ms","url":null,"abstract":"\u0000 This work studies the rheological properties of aqueous solutions of acrylamide copolymers. The prevailing role of elastic properties over viscous properties in predicting the proppant suspension capacity of the resulting fracturing fluid is shown. Furthermore, the potential of the use of oscillatory rheometry for studying fracturing fluid stability is demonstrated.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"117 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84888454","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}
L. Khakimova, A. Isaeva, V. Dobrozhanskiy, Y. Podladchikov
We discuss numerical simulation of carbon dioxide injection considered by oil and gas companies. Complex behavior of multicomponent reservoir fluids mixed with carbon dioxide may cause the occurrence of vapor-liquid-liquid equilibria (VLLE), salt precipitation in aquifers, pore-clogging, etc. We propose a simple algorithm for phase equilibria calculations based on the minimization of the multicomponent system free energy. This algorithm can be used to calculate phase separations and component partitioning between the phases under various conditions (critical region, two- and three-phase equilibria, etc.). We demonstrate the applicability of the proposed algorithm in a series of calculations. We consider binary and ternary mixtures that include carbon dioxide and hydrocarbons. We examine the algorithm in two- and three-phase equilibrium calculations and compare its performance with the popular iterative fugacity equilibration technique. We show that both calculation techniques give near-identical results for the considered mixtures. Thus, we show that the free energy minimization algorithm can be used interchangeably with the fugacity equilibration technique for calculating phase equilibria. This algorithm is applicable for VLLE calculations, which is important when considering multicomponent reservoir fluids that include carbon dioxide.
{"title":"Direct Energy Minimization Algorithm for Numerical Simulation of Carbon Dioxide Injection","authors":"L. Khakimova, A. Isaeva, V. Dobrozhanskiy, Y. Podladchikov","doi":"10.2118/206611-ms","DOIUrl":"https://doi.org/10.2118/206611-ms","url":null,"abstract":"\u0000 We discuss numerical simulation of carbon dioxide injection considered by oil and gas companies. Complex behavior of multicomponent reservoir fluids mixed with carbon dioxide may cause the occurrence of vapor-liquid-liquid equilibria (VLLE), salt precipitation in aquifers, pore-clogging, etc. We propose a simple algorithm for phase equilibria calculations based on the minimization of the multicomponent system free energy. This algorithm can be used to calculate phase separations and component partitioning between the phases under various conditions (critical region, two- and three-phase equilibria, etc.). We demonstrate the applicability of the proposed algorithm in a series of calculations. We consider binary and ternary mixtures that include carbon dioxide and hydrocarbons. We examine the algorithm in two- and three-phase equilibrium calculations and compare its performance with the popular iterative fugacity equilibration technique. We show that both calculation techniques give near-identical results for the considered mixtures. Thus, we show that the free energy minimization algorithm can be used interchangeably with the fugacity equilibration technique for calculating phase equilibria. This algorithm is applicable for VLLE calculations, which is important when considering multicomponent reservoir fluids that include carbon dioxide.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 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":"75015615","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
In this paper the simplified way is proposed for predicting the dynamics of liquid production and estimating the parameters of the oil reservoir using diagnostic curves, which are a generalization of analytical approaches, partially compared with the results of calculations on 3D simulation models and with actual well production data.
{"title":"Diagnostic Plots for Production Decline During the Transition of Oil Field Development From Depletion to Water Injection","authors":"V. Syrtlanov, Y. Golovatskiy, I. Ishimov","doi":"10.2118/206499-ms","DOIUrl":"https://doi.org/10.2118/206499-ms","url":null,"abstract":"\u0000 In this paper the simplified way is proposed for predicting the dynamics of liquid production and estimating the parameters of the oil reservoir using diagnostic curves, which are a generalization of analytical approaches, partially compared with the results of calculations on 3D simulation models and with actual well production data.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 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":"75143112","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}
Alexander Vitalyevich Tsarenko, V. Tarsky, Lisa Jane Robson
The objective of this article is to share an evaluation of the background, drilling outcomes and production and reservoir pressure impacts from two years of monitoring the first commingled up-dip SMART water injector drilled in the Piltun area of the Piltun-Astokhskoye offshore oil and gas field, located in Sakhalin, far east of Russia. The unique aspect of this water injector is that it was drilled into the up-dip gas caps of two separate reservoirs to provide pressure support to commingled oil producers, complementing the down-dip water injectors already in place. This article highlights some details of the well maturation decisions and expectations based on output of the dynamic modelling studies. Drilling outcomes and well performance is compared to expectations. Initial results of the surveillance programme and field data analysis based on a two-year monitoring period are discussed to show intermediate outcomes of up-dip water injection in the Piltun area. Finally, remaining questions and uncertainties are shared. Piltun-Astokhskoye is a complex multi-reservoir offshore oil and gas field with sizeable gas caps, significant heterogeneity both between and within reservoirs and a complex production history involving commingled oil producers and water injectors. Limited data is available to assess the impact of development decisions. Integrated analysis using multiple data sources and back-to-basics geology and reservoir engineering is required to understand how the reservoirs are responding to up-dip water injection, in order to predict future performance and make informed decisions to optimise the Piltun development over the long term. Surveillance data shows that up-dip water injection is effective in increasing reservoir pressure and oil recovery in one of the reservoirs, whilst having little impact on the other. Analysis shows that variable impact is due to the influence of gas cap size on up-dip water injection efficiency and the risk of trapped gas volumes due to water injection into the gas cap. The importance of integration between different sources of surveillance data and analytical tools to complete a comprehensive and reliable analysis is shown.
{"title":"Implementation and Intermediate Monitoring Outcomes of the First Commingled Up-Dip SMART Water Injection Well in PA-B Platform Piltun-Astokhskoye Offshore Oil and Gas Field","authors":"Alexander Vitalyevich Tsarenko, V. Tarsky, Lisa Jane Robson","doi":"10.2118/206503-ms","DOIUrl":"https://doi.org/10.2118/206503-ms","url":null,"abstract":"\u0000 The objective of this article is to share an evaluation of the background, drilling outcomes and production and reservoir pressure impacts from two years of monitoring the first commingled up-dip SMART water injector drilled in the Piltun area of the Piltun-Astokhskoye offshore oil and gas field, located in Sakhalin, far east of Russia.\u0000 The unique aspect of this water injector is that it was drilled into the up-dip gas caps of two separate reservoirs to provide pressure support to commingled oil producers, complementing the down-dip water injectors already in place. This article highlights some details of the well maturation decisions and expectations based on output of the dynamic modelling studies. Drilling outcomes and well performance is compared to expectations. Initial results of the surveillance programme and field data analysis based on a two-year monitoring period are discussed to show intermediate outcomes of up-dip water injection in the Piltun area. Finally, remaining questions and uncertainties are shared.\u0000 Piltun-Astokhskoye is a complex multi-reservoir offshore oil and gas field with sizeable gas caps, significant heterogeneity both between and within reservoirs and a complex production history involving commingled oil producers and water injectors. Limited data is available to assess the impact of development decisions. Integrated analysis using multiple data sources and back-to-basics geology and reservoir engineering is required to understand how the reservoirs are responding to up-dip water injection, in order to predict future performance and make informed decisions to optimise the Piltun development over the long term.\u0000 Surveillance data shows that up-dip water injection is effective in increasing reservoir pressure and oil recovery in one of the reservoirs, whilst having little impact on the other. Analysis shows that variable impact is due to the influence of gas cap size on up-dip water injection efficiency and the risk of trapped gas volumes due to water injection into the gas cap. The importance of integration between different sources of surveillance data and analytical tools to complete a comprehensive and reliable analysis is shown.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"8 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76105067","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}
Digital rock analysis has proven to be useful for the prediction of petrophysical properties of conventional reservoirs, where the pore space is captured well by a modern µCT scanner with a resolution of 1-5 µm. Nevertheless, this resolution is not enough to accurately capture the pore space of tight (low-permeable) rock samples. As a result, derived digital rock models do not reflect the real rock topology, and permeability predictions yield unreliable results. Our approach deploys high-contrast µCT scanning technique and Focused Ion Beam milling combined with Scanning Electron Microscopy to improve the quality of digital rock models and, hence, the permeability prediction. This workflow is successfully applied to a low-permeable rock sample of Achimov deposits. The computed permeability compares well to the experimental value.
{"title":"Application of High-Contrast µCT and FIB-SEM for the Improvement in the Permeability Prediction of Tight Rock Samples","authors":"A. Avdonin, M. Ebadi, V. Krutko","doi":"10.2118/206588-ms","DOIUrl":"https://doi.org/10.2118/206588-ms","url":null,"abstract":"\u0000 Digital rock analysis has proven to be useful for the prediction of petrophysical properties of conventional reservoirs, where the pore space is captured well by a modern µCT scanner with a resolution of 1-5 µm. Nevertheless, this resolution is not enough to accurately capture the pore space of tight (low-permeable) rock samples. As a result, derived digital rock models do not reflect the real rock topology, and permeability predictions yield unreliable results. Our approach deploys high-contrast µCT scanning technique and Focused Ion Beam milling combined with Scanning Electron Microscopy to improve the quality of digital rock models and, hence, the permeability prediction. This workflow is successfully applied to a low-permeable rock sample of Achimov deposits. The computed permeability compares well to the experimental value.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"53 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86696696","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. Gubanova, Bulat A. Khabibullin, D. Orlov, D. Koroteev
To reduce inefficient costs and environmental risks, oil companies strive to optimize the process of hydrocarbon production at all stages of field development, including geological and technical works at wells. In particular, it is important to predict fluid production with high accuracy. 3D hydrodynamic modeling is a generally accepted technique for solving this problem. It provides reliable results but requires many input data, computational resources, and time for calculations. Since the decision-making process has to be reactive, it is necessary to develop a simultaneously precise and prompt predictive instrument for quick forecasts of liquid production. The most promising tools for these purposes are proxy models based on solving the material balance equation. They adapt to the existing historical data even without PVT properties and reservoir data. Some of the most popular approaches are proxy models such as Capacitance Resistance Models (CRM). CR-type model is a material balance-based flow model, which provides preferable transmissibility trends, the presence of sealing or leaking faults with compressibility effects in consideration, and dissipation between injector-producer pairs. It is a data-driven model with adjustable time constants and interwell connectivity parameters. Before the model tuning, all parameters must be initialized with analytical or random approximations, and then they can be found by an appropriate optimization procedure. Historical-based Capacitance Models can be applied to poorly studied fields. Besides, they give an opportunity to rapidly optimize field development strategy by making calculations with different well exploitation parameters. They only require historical data of hydrocarbon production volumes, injection profiles, and bottom-hole pressure dynamics as input data. One of the main is that properties in the interwell space are estimated approximately and considered to be constant throughout the entire development history. However, this is a weak assumption in the case of including well interventions and stimulations. Thus, the main goal of this work is to adjust coefficients online to changes in well operation modes, introducing new wells or shut-in the existing ones. Since the governing equation includes the considered CRM improvement, users can perform optimization over different timespans, including "special" intervals. As a result, weighting connectivity parameters of the model can be depicted on a map of well interactions versus time.
{"title":"Modified CR-Type Material Balance Model for Well Production Forecasts in Case of Well Treatments","authors":"A. Gubanova, Bulat A. Khabibullin, D. Orlov, D. Koroteev","doi":"10.2118/206511-ms","DOIUrl":"https://doi.org/10.2118/206511-ms","url":null,"abstract":"\u0000 To reduce inefficient costs and environmental risks, oil companies strive to optimize the process of hydrocarbon production at all stages of field development, including geological and technical works at wells. In particular, it is important to predict fluid production with high accuracy. 3D hydrodynamic modeling is a generally accepted technique for solving this problem. It provides reliable results but requires many input data, computational resources, and time for calculations. Since the decision-making process has to be reactive, it is necessary to develop a simultaneously precise and prompt predictive instrument for quick forecasts of liquid production. The most promising tools for these purposes are proxy models based on solving the material balance equation. They adapt to the existing historical data even without PVT properties and reservoir data. Some of the most popular approaches are proxy models such as Capacitance Resistance Models (CRM).\u0000 CR-type model is a material balance-based flow model, which provides preferable transmissibility trends, the presence of sealing or leaking faults with compressibility effects in consideration, and dissipation between injector-producer pairs. It is a data-driven model with adjustable time constants and interwell connectivity parameters. Before the model tuning, all parameters must be initialized with analytical or random approximations, and then they can be found by an appropriate optimization procedure. Historical-based Capacitance Models can be applied to poorly studied fields. Besides, they give an opportunity to rapidly optimize field development strategy by making calculations with different well exploitation parameters. They only require historical data of hydrocarbon production volumes, injection profiles, and bottom-hole pressure dynamics as input data. One of the main is that properties in the interwell space are estimated approximately and considered to be constant throughout the entire development history. However, this is a weak assumption in the case of including well interventions and stimulations.\u0000 Thus, the main goal of this work is to adjust coefficients online to changes in well operation modes, introducing new wells or shut-in the existing ones. Since the governing equation includes the considered CRM improvement, users can perform optimization over different timespans, including \"special\" intervals. As a result, weighting connectivity parameters of the model can be depicted on a map of well interactions versus time.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"24 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78206716","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}
Andrei Tsyhankou, Alyaksandr Kanyushenka, Alyaksandr Hrudzinin, Alyaksei Kudrashou
The results of the well 10s2-Savichskaya drilling, laboratory core research are set out. Based on the results of integration the latest methods of wire line survey, laboratory core samples research, seismic facies analysis, typical lithotypes of the Savichsko-Bobrovichi area rocks were identified, reservoir features were predicted, the prospects of inter-salt deposits for identifying accumulations of hydrocarbons in unconventional reservoirs were substantiated. A perspective zone was identified and recommendations for drilling a pilot bore were given.
{"title":"Specification of the Geological Structure of the Inter-Salt Sediments of the Savichskoye Area Based on the Results of Well ?10S2 Drilling and Performing 3D Seismic Surveys in Order to Assess the Prospects for Identifying Hydrocarbons in Low-Permeability Reservoirs","authors":"Andrei Tsyhankou, Alyaksandr Kanyushenka, Alyaksandr Hrudzinin, Alyaksei Kudrashou","doi":"10.2118/206596-ms","DOIUrl":"https://doi.org/10.2118/206596-ms","url":null,"abstract":"\u0000 The results of the well 10s2-Savichskaya drilling, laboratory core research are set out. Based on the results of integration the latest methods of wire line survey, laboratory core samples research, seismic facies analysis, typical lithotypes of the Savichsko-Bobrovichi area rocks were identified, reservoir features were predicted, the prospects of inter-salt deposits for identifying accumulations of hydrocarbons in unconventional reservoirs were substantiated. A perspective zone was identified and recommendations for drilling a pilot bore were given.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"29 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78285559","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. Radosavljević, M. Naugolnov, Milos Bozic, R. Sukhanov
Missing seismic data is largely present problem in the world. Lack of seismic data usually occurs due to some form of natural obstacle or legislative prohibitions of seismic exploration. Restoration of seismic data would allow locating of new oil traps and reduce the risk of unsuccessful drillings. The approach is based on deep learning (image inpainting) techniques, which will be applied on inline and crossline sections of a given 3-d seismic cube, in order to restore missing parts of sections. The study was provided for non-commercial purpose for the aims of scientific research. Data used in our experiments comes from open source typical Western Siberia field. Our approach uses Generative Adversarial Networks (GANs) for completing missing parts of images (sections), based on known parts. Method can be used for restoration of arbitrarily-shaped missing parts of seismic cube, but also for extrapolation purposes. Metrics used for model evaluation are correlation coefficient and mean absolute percentage error (MAPE) between original and inpainted parts of data. This paper applies modern approach from growing image inpainting field to restore missing data, even if it's irregularly-shaped and very large. Using very powerful GANs is what gives this model ability to learn difficult inpainting scenarios, but also implicates challenging and time-consuming training process. Accurate estimation of model performances in different scenarios provides an exact instruction manual for a geologist, which helps him to identify cases where our model should be applied.
{"title":"Restoration of Seismic Data Using Inpainting and EdgeConnect","authors":"M. Radosavljević, M. Naugolnov, Milos Bozic, R. Sukhanov","doi":"10.2118/206523-ms","DOIUrl":"https://doi.org/10.2118/206523-ms","url":null,"abstract":"\u0000 Missing seismic data is largely present problem in the world. Lack of seismic data usually occurs due to some form of natural obstacle or legislative prohibitions of seismic exploration. Restoration of seismic data would allow locating of new oil traps and reduce the risk of unsuccessful drillings. The approach is based on deep learning (image inpainting) techniques, which will be applied on inline and crossline sections of a given 3-d seismic cube, in order to restore missing parts of sections. The study was provided for non-commercial purpose for the aims of scientific research. Data used in our experiments comes from open source typical Western Siberia field. Our approach uses Generative Adversarial Networks (GANs) for completing missing parts of images (sections), based on known parts. Method can be used for restoration of arbitrarily-shaped missing parts of seismic cube, but also for extrapolation purposes. Metrics used for model evaluation are correlation coefficient and mean absolute percentage error (MAPE) between original and inpainted parts of data.\u0000 This paper applies modern approach from growing image inpainting field to restore missing data, even if it's irregularly-shaped and very large. Using very powerful GANs is what gives this model ability to learn difficult inpainting scenarios, but also implicates challenging and time-consuming training process. Accurate estimation of model performances in different scenarios provides an exact instruction manual for a geologist, which helps him to identify cases where our model should be applied.","PeriodicalId":11052,"journal":{"name":"Day 3 Thu, October 14, 2021","volume":"35 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73796742","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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