The complex interbedded heterogeneous reservoirs of the Severo-Komsomolskoye field are developed by horizontal wells in which, as part of the pilot project's scope, autonomous inflow control devices (AICD) are installed to prevent early coning and gas breakthroughs in long horizontal sections and reduce sand production, which is a problem aggravated by an extremely low mechanical strength of the terrigenous deposits occurring in the Pokur formation of the Cenomanian stage in this area. The zones produced through AICDs are separated by swell packers. The issue of AICD effectiveness is discussed in the publications by Solovyev (2019), Shestov (2015), Byakov (2019) and some others. One of the methods used for monitoring horizontal sections with AICDs is production logging (PLT). However, due to the complexity of logging objectives, the use of conventional logging techniques makes the PLT unfeasible, considering the costs of preparing and carrying out the downhole operations. This paper provides some case studies of the Through-Barrier Diagnostics application, including passive spectral acoustics (spectral acoustic logging) and thermohydrodynamic modelling for the purpose of effective estimation of reservoir flows behind the liner with AICDs installed and well integrity diagnostics. As a result of the performed diagnostics, the well completion strategy was updated and optimised according to the log interpretation results, and one well intervention involving a cement squeeze with a straddle-packer assembly was carried out.
{"title":"From Completion Design to Efficiency Analysis of Inflow Control Device: Comprehensive Approach for AICD Implementation for Thin Oil Rim Field Development Efficiency Improvement","authors":"T. Solovyev, N. Mikhaylov","doi":"10.2118/206413-ms","DOIUrl":"https://doi.org/10.2118/206413-ms","url":null,"abstract":"\u0000 The complex interbedded heterogeneous reservoirs of the Severo-Komsomolskoye field are developed by horizontal wells in which, as part of the pilot project's scope, autonomous inflow control devices (AICD) are installed to prevent early coning and gas breakthroughs in long horizontal sections and reduce sand production, which is a problem aggravated by an extremely low mechanical strength of the terrigenous deposits occurring in the Pokur formation of the Cenomanian stage in this area.\u0000 The zones produced through AICDs are separated by swell packers. The issue of AICD effectiveness is discussed in the publications by Solovyev (2019), Shestov (2015), Byakov (2019) and some others.\u0000 One of the methods used for monitoring horizontal sections with AICDs is production logging (PLT). However, due to the complexity of logging objectives, the use of conventional logging techniques makes the PLT unfeasible, considering the costs of preparing and carrying out the downhole operations.\u0000 This paper provides some case studies of the Through-Barrier Diagnostics application, including passive spectral acoustics (spectral acoustic logging) and thermohydrodynamic modelling for the purpose of effective estimation of reservoir flows behind the liner with AICDs installed and well integrity diagnostics.\u0000 As a result of the performed diagnostics, the well completion strategy was updated and optimised according to the log interpretation results, and one well intervention involving a cement squeeze with a straddle-packer assembly was carried out.","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"47 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80889540","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}
Vadim Andreevich Rubailo, K. Isakov, A. Shirobokov
This work is devoted to the analytical solution of the damping of the fracture of the hydraulic fracturing. A solution is obtained for changing the dimensionless conductivity of the crack due to a decrease in the conductivity of the proppant and its removal from the crack. The considered crack geometry corresponds to the Perkins-Kern analytical model, which allows us to take into account the change in the crack width depending on its length. To calculate the proppant conductivity, laboratory studies were used, the data of which were extrapolated in order to predict the destruction of proppant balls during the operation of a well with a fractured hydraulic fracturing.
{"title":"Analytical Solution for Determining Fracture Attenuation","authors":"Vadim Andreevich Rubailo, K. Isakov, A. Shirobokov","doi":"10.2118/206642-ms","DOIUrl":"https://doi.org/10.2118/206642-ms","url":null,"abstract":"\u0000 This work is devoted to the analytical solution of the damping of the fracture of the hydraulic fracturing. A solution is obtained for changing the dimensionless conductivity of the crack due to a decrease in the conductivity of the proppant and its removal from the crack. The considered crack geometry corresponds to the Perkins-Kern analytical model, which allows us to take into account the change in the crack width depending on its length. To calculate the proppant conductivity, laboratory studies were used, the data of which were extrapolated in order to predict the destruction of proppant balls during the operation of a well with a fractured hydraulic fracturing.","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"7 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83458245","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. I. Tonkonog, Y. Kaipov, Dmitry Sergeevich Pruglo
Production monitoring is essential not only for fiscal applications, but also for production optimization and efficient reservoir management. So, production measurements must be both accurate and frequent enough, revealing a consistent trend of well operating parameters. This is especially important for reservoirs of complex geology, like oil rim reservoirs in poorly consolidated sandstone formations with presence of aquifer and gas cap drive. Production monitoring can be implemented with different technologies, accuracy of monitoring is however affected by different factors like gas content, viscosity and temperature of produced fluids. Paper presents pragmatic approach and analysis of applicability of different measurement technologies: compact two-phase separator and two different multiphase metering technologies applied at oil wells of Tazovskoye field operated by LLC "Meretoyakhaneftegaz", which production conditions are very challenging due to high gas volume fraction of the produced fluid, high viscosities and low temperatures.
{"title":"Experience of Application of Different Multiphase Metering Technologies for Cold Production and High Viscosity Oil Systems","authors":"M. I. Tonkonog, Y. Kaipov, Dmitry Sergeevich Pruglo","doi":"10.2118/206483-ms","DOIUrl":"https://doi.org/10.2118/206483-ms","url":null,"abstract":"\u0000 Production monitoring is essential not only for fiscal applications, but also for production optimization and efficient reservoir management. So, production measurements must be both accurate and frequent enough, revealing a consistent trend of well operating parameters. This is especially important for reservoirs of complex geology, like oil rim reservoirs in poorly consolidated sandstone formations with presence of aquifer and gas cap drive. Production monitoring can be implemented with different technologies, accuracy of monitoring is however affected by different factors like gas content, viscosity and temperature of produced fluids. Paper presents pragmatic approach and analysis of applicability of different measurement technologies: compact two-phase separator and two different multiphase metering technologies applied at oil wells of Tazovskoye field operated by LLC \"Meretoyakhaneftegaz\", which production conditions are very challenging due to high gas volume fraction of the produced fluid, high viscosities and low temperatures.","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":"72719663","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. Samoilov, V. Pavlov, N. Pavlyukov, Aleksandr Timirtdinov
The objective of the work is to present an adequate workflow for conditioning geomechanical data and hydraulic fracturing design, adjustment and simultaneous verification of a MEM and hydraulic fracture models. These approaches are relevant for greenfields and also can be used when changing field development systems: from vertical fracked wells to a system of horizontal wells with multistage fracs. The paper provides examples of issues in hydraulic fracturing planning due to poor attention to the reliability and robustness of geomechanical data. Given the critically of data quality, the authors describe a holistic approach used in collecting, analysing and conditioning data for building a MEM (1D; if necessary, 3D) as the basis of a frac design. Mini-frac is considered not only as a tool for setting the hydraulic fracturing design parameters, but also as a source of data for cross-calibration between the MEM and the hydraulic fracture models. Case studies of various HF models will demonstrate the influence of MEM-and-frac uncertainties and the tools for considering them in practical HF modelling. An approach to systematic clustering of input data for HF designs is described. The importance of measuring the fracture heights is stressed as a source of data for cross-calibration of HF and GM models. The correct sequence of work, data consolidation and successive data refinement helps to maintain the database of elastic and strength properties of various target reservoirs, which proves the demand for core analysis and well logging, as well as geomechanical modelling. The improved quality of HF designs leads to better reliability of forecasts and proposed field development and individual wellwork strategies. The close integration of GM studies and modelling with HF design building enhances the operation culture, accelerates and streamlines the HF model build and validation processes, which can be a pace-setting experience for other oil and gas industries that are GM data users. The TNNC and RN-CEPiTR teams work in close cooperation and provide GM and HF integration to assess the fracture height in the target reservoirs at the Company's assets in order to improve the quality of HF modelling. The uncertainty influence on the HF design is reducing, so as the risks of screen-out and the risks of breakthrough into undesirable zones. The approach streamlines the engineering support for the hydraulic fracturing activity and understanding of the fracture parameters as the operations move from single-stage hydraulic fracturing to the optimized field development using horizontal wells with multi-stage hydraulic fracturing.
{"title":"Integrated Geomechanical Modeling and Hydraulic Fracturing Design: From Particular Cases to the Overall Result","authors":"M. Samoilov, V. Pavlov, N. Pavlyukov, Aleksandr Timirtdinov","doi":"10.2118/206641-ms","DOIUrl":"https://doi.org/10.2118/206641-ms","url":null,"abstract":"\u0000 \u0000 \u0000 The objective of the work is to present an adequate workflow for conditioning geomechanical data and hydraulic fracturing design, adjustment and simultaneous verification of a MEM and hydraulic fracture models. These approaches are relevant for greenfields and also can be used when changing field development systems: from vertical fracked wells to a system of horizontal wells with multistage fracs.\u0000 \u0000 \u0000 \u0000 The paper provides examples of issues in hydraulic fracturing planning due to poor attention to the reliability and robustness of geomechanical data. Given the critically of data quality, the authors describe a holistic approach used in collecting, analysing and conditioning data for building a MEM (1D; if necessary, 3D) as the basis of a frac design.\u0000 Mini-frac is considered not only as a tool for setting the hydraulic fracturing design parameters, but also as a source of data for cross-calibration between the MEM and the hydraulic fracture models. Case studies of various HF models will demonstrate the influence of MEM-and-frac uncertainties and the tools for considering them in practical HF modelling. An approach to systematic clustering of input data for HF designs is described. The importance of measuring the fracture heights is stressed as a source of data for cross-calibration of HF and GM models.\u0000 \u0000 \u0000 \u0000 The correct sequence of work, data consolidation and successive data refinement helps to maintain the database of elastic and strength properties of various target reservoirs, which proves the demand for core analysis and well logging, as well as geomechanical modelling. The improved quality of HF designs leads to better reliability of forecasts and proposed field development and individual wellwork strategies.\u0000 The close integration of GM studies and modelling with HF design building enhances the operation culture, accelerates and streamlines the HF model build and validation processes, which can be a pace-setting experience for other oil and gas industries that are GM data users.\u0000 \u0000 \u0000 \u0000 The TNNC and RN-CEPiTR teams work in close cooperation and provide GM and HF integration to assess the fracture height in the target reservoirs at the Company's assets in order to improve the quality of HF modelling. The uncertainty influence on the HF design is reducing, so as the risks of screen-out and the risks of breakthrough into undesirable zones.\u0000 The approach streamlines the engineering support for the hydraulic fracturing activity and understanding of the fracture parameters as the operations move from single-stage hydraulic fracturing to the optimized field development using horizontal wells with multi-stage hydraulic fracturing.\u0000","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"6 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90007168","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 aim of the work is to optimize the fresh water treatment design, frequency and production regimes (maximize NPV of the well operation) for wells with high NaCl content formation water (brines) production, which are very common for the Eastern Siberia, and forecast productivity index (PI) decline rates and production profiles for the wells by means of halite deposition model for brine flow in porous media united with fresh water treatment model and economic model. New numerical halite deposition model for brine flow in porous media is developed based on Darcy's law and equation of halite precipitation dynamics from formation water taking into account the fresh water treatments, solubility of descipitated halite in the fresh water and permeability profile. It enables to predict deposited halite saturation (Shalite), dynamic porosity and permeability radially and versus time. Thus, we can forecast PI versustime and unite production and economic models,vary fresh water treatment design, frequency andproduction regimes for the given geological conditions and to determine treatment design, frequency and production regimes that brings the maximum NPV.PI decline rates and exploitation factor are calculated and analyzed for different scenarios of the fresh water treatment design, frequency and production regimes. These main conclusions are made from the results of the work:
{"title":"Halite Precipitation in Brine Reservoirs: Prediction and Control by Numerical Model, Optimization of the Fresh Water Treatments and Well Production Regimes","authors":"Aleksei Dmitrievitch Andryushchenko","doi":"10.2118/206645-ms","DOIUrl":"https://doi.org/10.2118/206645-ms","url":null,"abstract":"\u0000 The aim of the work is to optimize the fresh water treatment design, frequency and production regimes (maximize NPV of the well operation) for wells with high NaCl content formation water (brines) production, which are very common for the Eastern Siberia, and forecast productivity index (PI) decline rates and production profiles for the wells by means of halite deposition model for brine flow in porous media united with fresh water treatment model and economic model.\u0000 New numerical halite deposition model for brine flow in porous media is developed based on Darcy's law and equation of halite precipitation dynamics from formation water taking into account the fresh water treatments, solubility of descipitated halite in the fresh water and permeability profile. It enables to predict deposited halite saturation (Shalite), dynamic porosity and permeability radially and versus time. Thus, we can forecast PI versustime and unite production and economic models,vary fresh water treatment design, frequency andproduction regimes for the given geological conditions and to determine treatment design, frequency and production regimes that brings the maximum NPV.PI decline rates and exploitation factor are calculated and analyzed for different scenarios of the fresh water treatment design, frequency and production regimes.\u0000 These main conclusions are made from the results of the work:","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"7 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87989650","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pavel Lutoev, D. Kuznetsov, I. Nikishin, E. Efimov, Radik Minakhmetov, I. Platonov, M. Nukhaev, V. Kabanov, Alexsandr Zaitsev
This paper presents a novel technology for identifying the inflow profile during the oil rim development using chromate desorption systems that makes it possible to solve one of the critical tasks related to long horizontal and multi-bottom-hole wells—optimizing the position of well relative to the contact boundaries to prevent early water breakthroughs and gas outs.
{"title":"The Use of Chromate Desorption Systems to Optimize the Position of the Wells Relative to the Contact Boundaries During the Development of Oil Rim Fields","authors":"Pavel Lutoev, D. Kuznetsov, I. Nikishin, E. Efimov, Radik Minakhmetov, I. Platonov, M. Nukhaev, V. Kabanov, Alexsandr Zaitsev","doi":"10.2118/206488-ms","DOIUrl":"https://doi.org/10.2118/206488-ms","url":null,"abstract":"\u0000 This paper presents a novel technology for identifying the inflow profile during the oil rim development using chromate desorption systems that makes it possible to solve one of the critical tasks related to long horizontal and multi-bottom-hole wells—optimizing the position of well relative to the contact boundaries to prevent early water breakthroughs and gas outs.","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79834309","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. Shtun, Y. Kaipov, Fanise Kamalov, B. Akbayev, V. Blinov
Caspian offshore is reach for hydrocarbon reserves. The fields are made of multi-zone carbonate and sandstone reservoirs with significant variation of properties having high pressure (HP), high temperature (HT) and high H2S concentration in reservoir fluid. These challenges pose significant challenges to conduct the formation and multi-zone reservoir testing in a safe and informative manner. The dynamic reservoir evaluation program consists of formation pressure and its profile measurements, fluid pump-out for confirming the fluid type and sampling performed with wireline formation testers (FT) in open-hole and multi-zone well test for productivity estimation with drill-stem test (DST) designed for offshore environment with HP and high H2S. The project was planned and executed in an integrated manner, where the well construction design and selection of drilling and completion fluids has to improve the chance of success for FT and DST by taking into accound the downhole tool sizes and complex geological conditions. The open-hole formation testing and well testing in cased-hole were combined to provide enough information for characterizing multi-zone reservoirs by minimizing the drilling rig time. The well testing program was optimized in terms of number of zones for testing and necessity to acidize the reservoir based on formation testing data. The given methodolgy allowed to efficiently conduct the formation testing and well testing at two recently drilled offshore wells with multi-zone reservoirs. It was the first integrated dynamic reservoir evaluation project for such complex geological conditions in Middle part of Caspian offshore. This paper demonstrates the lessons learnt from two wells and offers the methodology for planning the evaluation for similar fields.
{"title":"Optimized Multi-Zone Dynamic Reservoir Evaluation in the Middle Caspian","authors":"S. Shtun, Y. Kaipov, Fanise Kamalov, B. Akbayev, V. Blinov","doi":"10.2118/206492-ms","DOIUrl":"https://doi.org/10.2118/206492-ms","url":null,"abstract":"\u0000 Caspian offshore is reach for hydrocarbon reserves. The fields are made of multi-zone carbonate and sandstone reservoirs with significant variation of properties having high pressure (HP), high temperature (HT) and high H2S concentration in reservoir fluid. These challenges pose significant challenges to conduct the formation and multi-zone reservoir testing in a safe and informative manner.\u0000 The dynamic reservoir evaluation program consists of formation pressure and its profile measurements, fluid pump-out for confirming the fluid type and sampling performed with wireline formation testers (FT) in open-hole and multi-zone well test for productivity estimation with drill-stem test (DST) designed for offshore environment with HP and high H2S.\u0000 The project was planned and executed in an integrated manner, where the well construction design and selection of drilling and completion fluids has to improve the chance of success for FT and DST by taking into accound the downhole tool sizes and complex geological conditions.\u0000 The open-hole formation testing and well testing in cased-hole were combined to provide enough information for characterizing multi-zone reservoirs by minimizing the drilling rig time. The well testing program was optimized in terms of number of zones for testing and necessity to acidize the reservoir based on formation testing data.\u0000 The given methodolgy allowed to efficiently conduct the formation testing and well testing at two recently drilled offshore wells with multi-zone reservoirs.\u0000 It was the first integrated dynamic reservoir evaluation project for such complex geological conditions in Middle part of Caspian offshore. This paper demonstrates the lessons learnt from two wells and offers the methodology for planning the evaluation for similar fields.","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"67 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90730433","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}
Proppant is one of the key aspects of a successful fracturing treatment and subsequent well production, and its quality is strictly controlled by ISO 13503-2, an international standard for proppant testing. Proppant suppliers, oilfield companies and their clients all around the world rely on the standard measurement procedures and limit values to ensure the quality of a product they produce or use for fracturing operations. ISO 13503-2 prescribes testing procedures; however, the standard does not contain information about uncertainty of final measurements. This information is essential for consistent quality assurance, for resolving inconsistencies between different laboratories, and for comparing properties of different products. An interlaboratory study was organized to evaluate the precision of ISO 13503-2 proppant testing. Four proppant samples were distributed among proppant quality control laboratories all around the world; 17 laboratories participated in the study. The obtained test data were used to calculate repeatability and reproducibility standard deviations (in accordance with ISO 5725-2) and uncertainty of ISO 13503-2 test data (in accordance with ISO 21748). The study showed that most proppant parameters measured using ISO 13503-2 methods yielded high uncertainty. For example, for turbidity and acid solubility values, the uncertainty was up to ±50%. Uncertainty of roundness and sphericity values was ±0.1 since the values are estimated by operator, making the test quite subjective. For crush resistance, the highest uncertainty among tested samples, ±40%, was observed for an HSP 30/50 sample measured at 15,000 psi stress. For absolute density, a systematic difference between values obtained using gas pycnometers from different manufactures was observed; also, the equipment differs by repeatability characteristics. The results of the interlaboratory study allowed estimating the uncertainty of ISO 13503-2 test methods. It was shown that high measurement uncertainty for some critical proppant parameters should be considered for correct interpretation of the obtained test results.
{"title":"Evaluation of Accuracy and Uncertainty of ISO 13503-2 Proppant Testing","authors":"Galina Makashova, Stepan Yukhtarov","doi":"10.2118/206643-ms","DOIUrl":"https://doi.org/10.2118/206643-ms","url":null,"abstract":"\u0000 Proppant is one of the key aspects of a successful fracturing treatment and subsequent well production, and its quality is strictly controlled by ISO 13503-2, an international standard for proppant testing. Proppant suppliers, oilfield companies and their clients all around the world rely on the standard measurement procedures and limit values to ensure the quality of a product they produce or use for fracturing operations. ISO 13503-2 prescribes testing procedures; however, the standard does not contain information about uncertainty of final measurements. This information is essential for consistent quality assurance, for resolving inconsistencies between different laboratories, and for comparing properties of different products.\u0000 An interlaboratory study was organized to evaluate the precision of ISO 13503-2 proppant testing. Four proppant samples were distributed among proppant quality control laboratories all around the world; 17 laboratories participated in the study. The obtained test data were used to calculate repeatability and reproducibility standard deviations (in accordance with ISO 5725-2) and uncertainty of ISO 13503-2 test data (in accordance with ISO 21748).\u0000 The study showed that most proppant parameters measured using ISO 13503-2 methods yielded high uncertainty. For example, for turbidity and acid solubility values, the uncertainty was up to ±50%. Uncertainty of roundness and sphericity values was ±0.1 since the values are estimated by operator, making the test quite subjective. For crush resistance, the highest uncertainty among tested samples, ±40%, was observed for an HSP 30/50 sample measured at 15,000 psi stress. For absolute density, a systematic difference between values obtained using gas pycnometers from different manufactures was observed; also, the equipment differs by repeatability characteristics.\u0000 The results of the interlaboratory study allowed estimating the uncertainty of ISO 13503-2 test methods. It was shown that high measurement uncertainty for some critical proppant parameters should be considered for correct interpretation of the obtained test results.","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"46 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77629360","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}
E. Yudin, G. Piotrovskiy, M. V. Petrova, A. Roshchektaev, N. Shtrobel
Requirements of targeted optimization are imposed on the hydraulic fracturing operations carried out in the conditions of borderline economic efficiency of fields taking into account geological and technological features. Consequently, the development of new analytical tools foranalyzing and planning the productivity of fractured wells, taking into account the structuralfeatures of the productive reservoir and inhomogeneous distribution of the fracture conductivity, is becoming highly relevant. The paper proposes a new approach of assessing the vertical hydraulic fracture productivityin a rectangular reservoir in a pseudo-steady state, based on reservoir resistivity concept described in the papers of Meyer et al. However, there is a free parameter in the case of modeling the productivity of a hydraulic fracture by the concept. The parameter describes the distribution of the inflow along the plane of the fracture. This paper presents a systematic approach to determining of the parameter. The resulting model allows to conduct an assessment of the influence of various complications in the fracture on the productivity index. During the research a method of determining the free parameter was developed,it was based on the obtained dependence of the inflow distribution on the coordinate along the fracture of finite conductivity. The methodology allowed to refine existent analytical solution of the Meyer et al. model, which, in turn, allowed to assess the influence of different fracture damages in the hydraulic fracture on the productivity index of the well. The work includes the cases of the presence of fracture damages at the beginning and at the end of the fracture. A hydraulic fracture model was built for each of the types of damages, it was based on the developed method, and also the solution of dimensionless productivity ratio was received. The results of the obtained solution were confirmed by comparison with the numerical solutions of commercial simulators and analytical models available in the literature. The advantage of the methodology is the resulting formulas for well productivity are relatively simple, even for exotic cases ofvariable conductivity fractures. The approaches and algorithms described in the paper assume the calculation of the productivity of a hydraulic fracture with variable conductivity and the presence of other complicatingfactors.The methodology of the paper can be used for analysis and diagnosis problems with formation hydraulic fracturing. The efficiency of the calculations allows using the presented methodology to solve inverse problems of determining the efficiency of the hydraulic fracturing operation.
{"title":"New Analytical Approach to Operational Assessment of Fractured Well Productivity with Variable Permeability","authors":"E. Yudin, G. Piotrovskiy, M. V. Petrova, A. Roshchektaev, N. Shtrobel","doi":"10.2118/206652-ms","DOIUrl":"https://doi.org/10.2118/206652-ms","url":null,"abstract":"\u0000 Requirements of targeted optimization are imposed on the hydraulic fracturing operations carried out in the conditions of borderline economic efficiency of fields taking into account geological and technological features. Consequently, the development of new analytical tools foranalyzing and planning the productivity of fractured wells, taking into account the structuralfeatures of the productive reservoir and inhomogeneous distribution of the fracture conductivity, is becoming highly relevant.\u0000 The paper proposes a new approach of assessing the vertical hydraulic fracture productivityin a rectangular reservoir in a pseudo-steady state, based on reservoir resistivity concept described in the papers of Meyer et al. However, there is a free parameter in the case of modeling the productivity of a hydraulic fracture by the concept. The parameter describes the distribution of the inflow along the plane of the fracture. This paper presents a systematic approach to determining of the parameter. The resulting model allows to conduct an assessment of the influence of various complications in the fracture on the productivity index.\u0000 During the research a method of determining the free parameter was developed,it was based on the obtained dependence of the inflow distribution on the coordinate along the fracture of finite conductivity. The methodology allowed to refine existent analytical solution of the Meyer et al. model, which, in turn, allowed to assess the influence of different fracture damages in the hydraulic fracture on the productivity index of the well. The work includes the cases of the presence of fracture damages at the beginning and at the end of the fracture. A hydraulic fracture model was built for each of the types of damages, it was based on the developed method, and also the solution of dimensionless productivity ratio was received. The results of the obtained solution were confirmed by comparison with the numerical solutions of commercial simulators and analytical models available in the literature. The advantage of the methodology is the resulting formulas for well productivity are relatively simple, even for exotic cases ofvariable conductivity fractures.\u0000 The approaches and algorithms described in the paper assume the calculation of the productivity of a hydraulic fracture with variable conductivity and the presence of other complicatingfactors.The methodology of the paper can be used for analysis and diagnosis problems with formation hydraulic fracturing. The efficiency of the calculations allows using the presented methodology to solve inverse problems of determining the efficiency of the hydraulic fracturing operation.","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"97 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88530728","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}
Asfandiyar Bigeldiyev, Assem Batu, Aidynbek Berdibekov, D. Kovyazin, D. Sidorov, Aidos Temirkhassov, Almas Zhumagulov, Yernar Narimanov
The current work is intended to show the application of a multiple realization approach to produce a strategic development plan for one of the mines in Karaganda coal basin. The presented workflow suggests using a comprehensive reservoir simulator for a history matching process of a coal pillars on a detailed 3D grid and application of sensitivity and uncertainty analyses to produce probabilistic forecast. The suggested workflow significantly differs from the standard approaches previously implemented in the Karaganda Basin. First, a dynamic model has been constructed based on integrated algorithm of petrophysical interpretation and full cycle of geological modeling. Secondly, for the first time in the region, dynamic modeling has been performed via a combination of history matching to the observed degassing data and multiple realization uncertainty analysis. Thirdly, the described model parameters with defined range of uncertainty has been incorporated into the forecasting of degassing efficiency in the mine using different well completion technology. From the hydrodynamic modeling point of view, the coal seam gas (CSG) reservoir is presented as a dual porosity medium: a coal matrix containing adsorbed gas and a network of natural fractures (cleats), which are initially saturated with water. This approach has allowed the proper description of dynamic processes occurring in CSG reservoirs. The gas production from a coal is subject to gas diffusion in coal micropores, the degree of fracture intensity and fracture permeability. By tuning these parameters within reasonable ranges, we have been able to history match our model to the observed data. Moreover, application of an uncertainty analysis has resulted in a range of output parameters (P10, P50, and P90) that were historically observed. Performed full cycle of CSG dynamic modelling including history matching, sensitivity, and uncertainty analyses has been performed to create a robust model with the predictive power. Based on the obtained results, different optimization technologies have been simulated for fast and efficient degassing through a multiple realization probabilistic approach. The coal reservoir presented in this work is characterized by very low effective permeability and final degassing efficiency depends on well-reservoir contact surface. The decrease of the well spacing led to a proportional increase of gas recovery which is very similar to unconventional reservoirs. Therefore, vertical and horizontal wells with hydraulic fractures have been concluded the most efficient way to develop coal seams with low effective permeability in a secondary medium.
{"title":"Dynamic Modeling of the Gas Discharge of a Mine in the Karaganda Coal Basin Under High Uncertainty Using a Multiple Realization Approach","authors":"Asfandiyar Bigeldiyev, Assem Batu, Aidynbek Berdibekov, D. Kovyazin, D. Sidorov, Aidos Temirkhassov, Almas Zhumagulov, Yernar Narimanov","doi":"10.2118/206415-ms","DOIUrl":"https://doi.org/10.2118/206415-ms","url":null,"abstract":"\u0000 The current work is intended to show the application of a multiple realization approach to produce a strategic development plan for one of the mines in Karaganda coal basin. The presented workflow suggests using a comprehensive reservoir simulator for a history matching process of a coal pillars on a detailed 3D grid and application of sensitivity and uncertainty analyses to produce probabilistic forecast.\u0000 The suggested workflow significantly differs from the standard approaches previously implemented in the Karaganda Basin. First, a dynamic model has been constructed based on integrated algorithm of petrophysical interpretation and full cycle of geological modeling. Secondly, for the first time in the region, dynamic modeling has been performed via a combination of history matching to the observed degassing data and multiple realization uncertainty analysis. Thirdly, the described model parameters with defined range of uncertainty has been incorporated into the forecasting of degassing efficiency in the mine using different well completion technology.\u0000 From the hydrodynamic modeling point of view, the coal seam gas (CSG) reservoir is presented as a dual porosity medium: a coal matrix containing adsorbed gas and a network of natural fractures (cleats), which are initially saturated with water. This approach has allowed the proper description of dynamic processes occurring in CSG reservoirs. The gas production from a coal is subject to gas diffusion in coal micropores, the degree of fracture intensity and fracture permeability. By tuning these parameters within reasonable ranges, we have been able to history match our model to the observed data. Moreover, application of an uncertainty analysis has resulted in a range of output parameters (P10, P50, and P90) that were historically observed.\u0000 Performed full cycle of CSG dynamic modelling including history matching, sensitivity, and uncertainty analyses has been performed to create a robust model with the predictive power. Based on the obtained results, different optimization technologies have been simulated for fast and efficient degassing through a multiple realization probabilistic approach. The coal reservoir presented in this work is characterized by very low effective permeability and final degassing efficiency depends on well-reservoir contact surface. The decrease of the well spacing led to a proportional increase of gas recovery which is very similar to unconventional reservoirs. Therefore, vertical and horizontal wells with hydraulic fractures have been concluded the most efficient way to develop coal seams with low effective permeability in a secondary medium.","PeriodicalId":11177,"journal":{"name":"Day 4 Fri, October 15, 2021","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89131344","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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