Heterogeneity is the basic characteristic of reservoir, which seriously affects the overall development effect of oilfield. In order to solve this problem, a new flooding system, soft microgel, has been developed in recent years. Its field test has obtained obvious effect of increasing oil and decreasing water. However, the research on its reservoir adaptability and displacement mechanism are still in the initial stage. Therefore, this paper has carried out relevant research work and introduced the field test results. Soft microgel particle dispersion is a heterogeneous system, composing of microgel particles and carrier fluid. In this paper, the microfluidic technology was used to simulate the particle separation phenomenon in the migration process of soft microgels. Guided by the theory of red blood cells in biological fluid mechanics, a mathematical model of concentration distribution of soft microgels in different channels was established. Furthermore, in order to explore its oil displacement mechanism and performance, micro and macro physical simulation experiments were carried out. Finally, its typical field application is introduced. Results show that, the separation phenomenon between soft microgel particles and carrier fluid occurs when injecting into the core. That is, soft microgel particles first enter the larger channel with low seepage resistance, while fluid turns into the smaller channel to displace oil. Therefore, by the cooperation between microgel particles and carrier fluid, soft microgel particle dispersion can effectively expand sweep volume. Furthermore, soft microgel particles can migrate, be trapped, deform in the porous medium. Based on the resistance coefficient, residual resistance coefficient and plugging rate, the migration and plugging modes of soft microgels can be divided into 3 modes: efficient plugging, normal plugging and low efficiency plugging. In the normal plugging mode, soft microgels can not only adjust the profile effectively in the early stage of injection, but also migrate to the deep reservoir and improve the injection pressure. Also, 3D macroscopic physical simulation experiments show that soft microgels can moderately plug the high permeability layer and improve the displacement effect of low permeability layer, which finally achieve the goal of enhanced oil recovery. Furthermore, soft microgel particle dispersion has been applied in 8 different reservoirs, and has achieved remarkable effect of increasing oil. Taking JX6ZD as an example, the daily oil production in the pilot test area increased from 25t/d to 75t/d, and the water content decreased by 38%. Therefore, through the lab physical simulation and field tests, the progressiveness of soft microgel particle dispersion can be proved. In this paper, the mechanism and performance of soft microgel particle dispersion are studied by a multidisciplinary approach. On this basis, the field test results are analyzed. The above research results prov
{"title":"Research on the Reservoir Adaptability and Oil Displacement Mechanism of a New Soft Microgel Particle Dispersion System","authors":"Zhe Sun, Xiaodong Kang, Risu Na, Jun Zhou","doi":"10.2118/201839-ms","DOIUrl":"https://doi.org/10.2118/201839-ms","url":null,"abstract":"\u0000 Heterogeneity is the basic characteristic of reservoir, which seriously affects the overall development effect of oilfield. In order to solve this problem, a new flooding system, soft microgel, has been developed in recent years. Its field test has obtained obvious effect of increasing oil and decreasing water. However, the research on its reservoir adaptability and displacement mechanism are still in the initial stage. Therefore, this paper has carried out relevant research work and introduced the field test results.\u0000 Soft microgel particle dispersion is a heterogeneous system, composing of microgel particles and carrier fluid. In this paper, the microfluidic technology was used to simulate the particle separation phenomenon in the migration process of soft microgels. Guided by the theory of red blood cells in biological fluid mechanics, a mathematical model of concentration distribution of soft microgels in different channels was established. Furthermore, in order to explore its oil displacement mechanism and performance, micro and macro physical simulation experiments were carried out. Finally, its typical field application is introduced.\u0000 Results show that, the separation phenomenon between soft microgel particles and carrier fluid occurs when injecting into the core. That is, soft microgel particles first enter the larger channel with low seepage resistance, while fluid turns into the smaller channel to displace oil. Therefore, by the cooperation between microgel particles and carrier fluid, soft microgel particle dispersion can effectively expand sweep volume. Furthermore, soft microgel particles can migrate, be trapped, deform in the porous medium. Based on the resistance coefficient, residual resistance coefficient and plugging rate, the migration and plugging modes of soft microgels can be divided into 3 modes: efficient plugging, normal plugging and low efficiency plugging. In the normal plugging mode, soft microgels can not only adjust the profile effectively in the early stage of injection, but also migrate to the deep reservoir and improve the injection pressure. Also, 3D macroscopic physical simulation experiments show that soft microgels can moderately plug the high permeability layer and improve the displacement effect of low permeability layer, which finally achieve the goal of enhanced oil recovery. Furthermore, soft microgel particle dispersion has been applied in 8 different reservoirs, and has achieved remarkable effect of increasing oil. Taking JX6ZD as an example, the daily oil production in the pilot test area increased from 25t/d to 75t/d, and the water content decreased by 38%. Therefore, through the lab physical simulation and field tests, the progressiveness of soft microgel particle dispersion can be proved.\u0000 In this paper, the mechanism and performance of soft microgel particle dispersion are studied by a multidisciplinary approach. On this basis, the field test results are analyzed. The above research results prov","PeriodicalId":359083,"journal":{"name":"Day 2 Tue, October 27, 2020","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129928654","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. Semenikhin, A. Shchepetnov, A. A. Reshytko, A. Sabirov, O. Osmonalieva, D. Egorov, B. Belozerov
In this work we pursued the goal of an automate cognitive system development capable for searching missed net pay zones within wells to extend a brownfield lifecycle via the involvement of new reserves into the field development. Additional research was dedicated to studying the possibility of knowledge transfer across different fields and the construction of the ranking model allowing fast expertise conduction of proposed intervals and evaluation of the proposed method on mature assesses. The proposed approach is based on deep learning and artificial neural networks architectures trained in a supervised mode using a provided human well logs interpretation. Our approach also utilizes transfer learning procedures in order to reuse knowledge extracted from the oilfield with sufficient data and improve the predictive qualities of the model on a target oilfield. Additionally, we proposed a ranking model that simulates expert decision-making process and evaluates oil saturation potential of proposed intervals by sorting it by a confidence level. Developed method was evaluated at the one of Gazpromneft brownfields, located in Western Siberia, Yamalo-Nenets region. The model was trained on a data from this field and its analogues with subsequent reinterpretation of the whole well log volume. Several hundreds of new net pay intervals were proposed and post-processed by ranking model. Then the list of proposed intervals was analyzed by an expert group including number of geologists, petrophysicists and reservoir engineers. Significant part of these intervals after detailed and comprehensive evaluation were marked as missed during previous manual well log interpretation conducted by petrophysicist and taken for the following fieldwork. Produced results confirmed applicability of proposed algorithm and proved its capability for localization of previously unrecognized net pay intervals.
{"title":"Missed Net Pay Zones Mature Oilfieds Via Injection Of Expert Knowledge in Deep Learning Algorithms","authors":"A. Semenikhin, A. Shchepetnov, A. A. Reshytko, A. Sabirov, O. Osmonalieva, D. Egorov, B. Belozerov","doi":"10.2118/201922-ms","DOIUrl":"https://doi.org/10.2118/201922-ms","url":null,"abstract":"\u0000 In this work we pursued the goal of an automate cognitive system development capable for searching missed net pay zones within wells to extend a brownfield lifecycle via the involvement of new reserves into the field development. Additional research was dedicated to studying the possibility of knowledge transfer across different fields and the construction of the ranking model allowing fast expertise conduction of proposed intervals and evaluation of the proposed method on mature assesses.\u0000 The proposed approach is based on deep learning and artificial neural networks architectures trained in a supervised mode using a provided human well logs interpretation. Our approach also utilizes transfer learning procedures in order to reuse knowledge extracted from the oilfield with sufficient data and improve the predictive qualities of the model on a target oilfield. Additionally, we proposed a ranking model that simulates expert decision-making process and evaluates oil saturation potential of proposed intervals by sorting it by a confidence level.\u0000 Developed method was evaluated at the one of Gazpromneft brownfields, located in Western Siberia, Yamalo-Nenets region. The model was trained on a data from this field and its analogues with subsequent reinterpretation of the whole well log volume. Several hundreds of new net pay intervals were proposed and post-processed by ranking model. Then the list of proposed intervals was analyzed by an expert group including number of geologists, petrophysicists and reservoir engineers. Significant part of these intervals after detailed and comprehensive evaluation were marked as missed during previous manual well log interpretation conducted by petrophysicist and taken for the following fieldwork. Produced results confirmed applicability of proposed algorithm and proved its capability for localization of previously unrecognized net pay intervals.","PeriodicalId":359083,"journal":{"name":"Day 2 Tue, October 27, 2020","volume":"3 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125584607","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. Burkhanov, A. Lutfullin, I. Ibragimov, A. Maksyutin
The composition and properties of oil change during its flow through the reservoir, which is associated with the high molecular weight resins and asphaltenes retained in the pores. Oil is retained in the thinnest capillaries and narrow contacts of hydrophilic mineral grains (capillary-retained oil) and as a film on the surface of hydrophobic minerals (oil films). To confirm this, core analysis tests were performed on three pre-prepared core columns made up of standard core samples with different porosity ϕ, absolute permeability k, irreducible water saturation Swir and other properties. Oil was flowing through the column and displaced by water with pre-determined physical properties. The properties of the core specimens, oil and water, as well as the thermobaric conditions of flow experiments were selected so that they corresponded to the reservoir conditions of the Pashian horizon of the Romashkinskoye oilfield of the Republic of Tatarstan. In the case of the mature Romashkinskoye oilfield, the relevant objective is to quantify and localize the remaining reserves of capillary-retained oil and oil films and substantiate effective technologies for their extraction. To prove that the composition of oil change during flow through porous media, the light absorption coefficient of oil kla was investigated that depends on the relative content of resins and asphaltenes in the oil. Oil was studied using a photometer in a continuous mode during the entire period of oil displacement test. Oil samples were collected and subjected to preparation at the inlet and outlet of the core column, their optical density D, light absorption and transmission coefficients were measured in vitro, and statistical data were processed. It has been found that regular changes in the oil kla occur both at the stage of the core column saturation with oil (a regular decrease), and as oil is displaced from the core samples by water (a regular increase). The identified patterns are the function of the rock and oil properties, the established rate of the column saturation with oil and oil displacement by water, and the amount of residual and displaced oil. The obtained data have shown the promising outlook for continuing laboratory experiments to study not only changes in the properties of oil when it is displaced by water, simulating the development processes, but also those occurring in the column as it is saturated with oil, simulating the processes of primary migration and accumulation of oil in a natural reservoir.
{"title":"Core Column Filtration Testing Supplemented by Measurements of Oil Optical Properties","authors":"R. Burkhanov, A. Lutfullin, I. Ibragimov, A. Maksyutin","doi":"10.2118/202023-ms","DOIUrl":"https://doi.org/10.2118/202023-ms","url":null,"abstract":"\u0000 The composition and properties of oil change during its flow through the reservoir, which is associated with the high molecular weight resins and asphaltenes retained in the pores. Oil is retained in the thinnest capillaries and narrow contacts of hydrophilic mineral grains (capillary-retained oil) and as a film on the surface of hydrophobic minerals (oil films). To confirm this, core analysis tests were performed on three pre-prepared core columns made up of standard core samples with different porosity ϕ, absolute permeability k, irreducible water saturation Swir and other properties. Oil was flowing through the column and displaced by water with pre-determined physical properties. The properties of the core specimens, oil and water, as well as the thermobaric conditions of flow experiments were selected so that they corresponded to the reservoir conditions of the Pashian horizon of the Romashkinskoye oilfield of the Republic of Tatarstan. In the case of the mature Romashkinskoye oilfield, the relevant objective is to quantify and localize the remaining reserves of capillary-retained oil and oil films and substantiate effective technologies for their extraction. To prove that the composition of oil change during flow through porous media, the light absorption coefficient of oil kla was investigated that depends on the relative content of resins and asphaltenes in the oil. Oil was studied using a photometer in a continuous mode during the entire period of oil displacement test. Oil samples were collected and subjected to preparation at the inlet and outlet of the core column, their optical density D, light absorption and transmission coefficients were measured in vitro, and statistical data were processed. It has been found that regular changes in the oil kla occur both at the stage of the core column saturation with oil (a regular decrease), and as oil is displaced from the core samples by water (a regular increase). The identified patterns are the function of the rock and oil properties, the established rate of the column saturation with oil and oil displacement by water, and the amount of residual and displaced oil. The obtained data have shown the promising outlook for continuing laboratory experiments to study not only changes in the properties of oil when it is displaced by water, simulating the development processes, but also those occurring in the column as it is saturated with oil, simulating the processes of primary migration and accumulation of oil in a natural reservoir.","PeriodicalId":359083,"journal":{"name":"Day 2 Tue, October 27, 2020","volume":"31 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122893626","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. Topchii, A. Kalmykov, G. Kalmykov, Mariia Fomina, D. Ivanova
The rocks of the Bazhenov high-carbon formation (BCHF) occurring in Western Siberia are notable for their complex heterogeneous structure and are characterized by a high content of organic matter (up to 35 wt.%). This formation is an oil and gas source, in which during the geological transformation under the influence of various processes, hydrocarbon compounds (HC) are separated from the solid organic substance - kerogen, the light part of which forms oil and gas. As a result of migration, these hydrocarbons saturate overlying reservoirs. However, during the process of dia- and catagenesis, pore space is also formed in the BCHF rocks, which is filled with the generated HC itself. In this case, the porosity is secondary, the structure of the pore space depends both on the composition of a particular interval or layer of rocks, and on the processes of additional exposure, for example, the development of rocks by hydrothermal fluids. As a result, in some areas, BCHF rocks have a high capacity and can belong to unconventional reservoirs, while in other areas in the rocks there is practically no developed pore space and interconnection between pores, nor a sufficient number of mobile hydrocarbon fluids that can provide oil flow, the kerogen in them is poorly transformed and is at the low stages of catagenesis. Studies conducted by a large number of scientists have shown that HC in BCHF rocks can be found in the form of oil (condensate, gas) and stationary compounds that occupy part of the pore space and partially block the mobility of light HC. Additionally, the BCHF source rocks contain kerogen, which, depending on the stage of conversion, has different residual generation potential and from which new HC can be separated during further transformations. The distribution of all the listed HC and the form of their content in the rock, the amount of kerogen generation potential are determined by the ongoing geological processes and should be predicted on each specific area to assess the prospects of the BCHF rocks. In fact, 3 types of resources can be allocated in the BCHF rocks, each of which requires a separate consideration. In the framework of this work, the following classification of BCHF resources is proposed: Reserves of mobile oil; Resources sorbed HC; The residual generating potential of kerogen. The paper presents a methodology for assessing linear resources of all three types in a particular well, and shows a methodology for calculating resources by area. In addition, experimental evidence is given of the presence of dependences of the calculated parameters on the GIS data depending on the catagenetic maturity of organic matter in rocks, and the possibility of converting organic matter under laboratory conditions and producing "synthetic" oil by realizing the generation potential of kerogen has been proved. The results obtained can then be applied to develop a methodology for assessing the resources of the BCHF.
{"title":"Evaluation of Hydrocarbon-Generating Potential of Bazhenov High-Carbon Formation","authors":"M. Topchii, A. Kalmykov, G. Kalmykov, Mariia Fomina, D. Ivanova","doi":"10.2118/201813-ms","DOIUrl":"https://doi.org/10.2118/201813-ms","url":null,"abstract":"\u0000 The rocks of the Bazhenov high-carbon formation (BCHF) occurring in Western Siberia are notable for their complex heterogeneous structure and are characterized by a high content of organic matter (up to 35 wt.%). This formation is an oil and gas source, in which during the geological transformation under the influence of various processes, hydrocarbon compounds (HC) are separated from the solid organic substance - kerogen, the light part of which forms oil and gas. As a result of migration, these hydrocarbons saturate overlying reservoirs. However, during the process of dia- and catagenesis, pore space is also formed in the BCHF rocks, which is filled with the generated HC itself. In this case, the porosity is secondary, the structure of the pore space depends both on the composition of a particular interval or layer of rocks, and on the processes of additional exposure, for example, the development of rocks by hydrothermal fluids. As a result, in some areas, BCHF rocks have a high capacity and can belong to unconventional reservoirs, while in other areas in the rocks there is practically no developed pore space and interconnection between pores, nor a sufficient number of mobile hydrocarbon fluids that can provide oil flow, the kerogen in them is poorly transformed and is at the low stages of catagenesis. Studies conducted by a large number of scientists have shown that HC in BCHF rocks can be found in the form of oil (condensate, gas) and stationary compounds that occupy part of the pore space and partially block the mobility of light HC. Additionally, the BCHF source rocks contain kerogen, which, depending on the stage of conversion, has different residual generation potential and from which new HC can be separated during further transformations.\u0000 The distribution of all the listed HC and the form of their content in the rock, the amount of kerogen generation potential are determined by the ongoing geological processes and should be predicted on each specific area to assess the prospects of the BCHF rocks. In fact, 3 types of resources can be allocated in the BCHF rocks, each of which requires a separate consideration. In the framework of this work, the following classification of BCHF resources is proposed:\u0000 Reserves of mobile oil; Resources sorbed HC; The residual generating potential of kerogen.\u0000 The paper presents a methodology for assessing linear resources of all three types in a particular well, and shows a methodology for calculating resources by area. In addition, experimental evidence is given of the presence of dependences of the calculated parameters on the GIS data depending on the catagenetic maturity of organic matter in rocks, and the possibility of converting organic matter under laboratory conditions and producing \"synthetic\" oil by realizing the generation potential of kerogen has been proved. The results obtained can then be applied to develop a methodology for assessing the resources of the BCHF.","PeriodicalId":359083,"journal":{"name":"Day 2 Tue, October 27, 2020","volume":"132 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133949144","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}
K. Rymarenko, M. Nukhaev, S. Grishchenko, A. Zaytsev, A. Golubtsov, Galymzhan Aitkaliev, N. Dadakin
One of the most important tasks when developing oil fields with horizontal or directional wells is the inflow distribution monitoring along the wellbore. Possible irregularities in the inflow are primarily associated with heterogeneity in the filtration distribution and capacitive properties along the wellbore, unevenness in the depression distribution, possible overfilling of the wellbore, partial or complete blockage of sand filters by mechanical impurities or clay material, imperfect development of the wells (when part of the mud cake remains on the wall of the well), gradual clogging of the bottomhole zone pores, water breakthroughs and gas outs, or other reasons. Inflow profile monitoring allows identifying why the well performance has decreased and timely planning and carrying out appropriate geological and technical measures. Also, this information allows timely updating hydrodynamic models of field development to properly make strategic decisions. This paper presents the results of bench tests of a new active thermometry technology using a distributed temperature measurement system
{"title":"Test Results of Active Thermometry Technology Using a Distributed Temperature Measurement System","authors":"K. Rymarenko, M. Nukhaev, S. Grishchenko, A. Zaytsev, A. Golubtsov, Galymzhan Aitkaliev, N. Dadakin","doi":"10.2118/202040-ms","DOIUrl":"https://doi.org/10.2118/202040-ms","url":null,"abstract":"\u0000 One of the most important tasks when developing oil fields with horizontal or directional wells is the inflow distribution monitoring along the wellbore. Possible irregularities in the inflow are primarily associated with heterogeneity in the filtration distribution and capacitive properties along the wellbore, unevenness in the depression distribution, possible overfilling of the wellbore, partial or complete blockage of sand filters by mechanical impurities or clay material, imperfect development of the wells (when part of the mud cake remains on the wall of the well), gradual clogging of the bottomhole zone pores, water breakthroughs and gas outs, or other reasons.\u0000 Inflow profile monitoring allows identifying why the well performance has decreased and timely planning and carrying out appropriate geological and technical measures. Also, this information allows timely updating hydrodynamic models of field development to properly make strategic decisions.\u0000 This paper presents the results of bench tests of a new active thermometry technology using a distributed temperature measurement system","PeriodicalId":359083,"journal":{"name":"Day 2 Tue, October 27, 2020","volume":"31 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127689904","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}
Zongyao Qi, Tong Liu, Changfeng Xi, Yunjun Zhang, D. Shen, Hertaer Mu, H. Dong, Aiping Zheng, Kequan Yu, X. Li, Youwei Jiang, Hongzhuang Wang, H. Li, T. Babadagli
It is challenging to enhance heavy oil recovery in the late stages of steam flooding. This challenge is due to the reduced residual oil saturation, the high steam-oil ratio, and the lower profitability. A field test of CO2-assisted steam flooding technology was carried out in the steam-flooded heavy oil reservoir in the J6 block of Xinjiang oil field (China). The field test showed a positive response to the CO2-assisted steam flooding treatment including a gradually increasing heavy oil production, a rise in formation pressure, a decrease in water cut, etc. The production wells in the test area mainly exhibited four types of production dynamics, while some production wells showed production dynamics that were completely different from those during steam flooding. After being flooded by CO2-assisted steam flooding, these wells exhibited a gravity drainage pattern without steam channeling issues, and hence could yield a stable oil production. Meanwhile, emulsified oil, together with CO2-foam, was observed to be produced in the production well, which agreed well with what was observed in the lab-scale tests. The reservoir-simulation-based prediction in the test reservoir shows that the CO2-assisted steam flooding technology can reduce the steam-oil ratio from 12 m3 (CWE)/t to 6 m3 (CWE)/t and yield a final recovery factor of 70%.
{"title":"A Field Pilot Test on CO2 Assisted Steam-Flooding in a Steam-flooded Heavy Oil Reservoir in China","authors":"Zongyao Qi, Tong Liu, Changfeng Xi, Yunjun Zhang, D. Shen, Hertaer Mu, H. Dong, Aiping Zheng, Kequan Yu, X. Li, Youwei Jiang, Hongzhuang Wang, H. Li, T. Babadagli","doi":"10.2118/201832-ms","DOIUrl":"https://doi.org/10.2118/201832-ms","url":null,"abstract":"\u0000 It is challenging to enhance heavy oil recovery in the late stages of steam flooding. This challenge is due to the reduced residual oil saturation, the high steam-oil ratio, and the lower profitability. A field test of CO2-assisted steam flooding technology was carried out in the steam-flooded heavy oil reservoir in the J6 block of Xinjiang oil field (China). The field test showed a positive response to the CO2-assisted steam flooding treatment including a gradually increasing heavy oil production, a rise in formation pressure, a decrease in water cut, etc. The production wells in the test area mainly exhibited four types of production dynamics, while some production wells showed production dynamics that were completely different from those during steam flooding. After being flooded by CO2-assisted steam flooding, these wells exhibited a gravity drainage pattern without steam channeling issues, and hence could yield a stable oil production. Meanwhile, emulsified oil, together with CO2-foam, was observed to be produced in the production well, which agreed well with what was observed in the lab-scale tests. The reservoir-simulation-based prediction in the test reservoir shows that the CO2-assisted steam flooding technology can reduce the steam-oil ratio from 12 m3 (CWE)/t to 6 m3 (CWE)/t and yield a final recovery factor of 70%.","PeriodicalId":359083,"journal":{"name":"Day 2 Tue, October 27, 2020","volume":"570 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116280561","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}
Modern technology of drilling and construction of horizontal wells allows for effective development of complex oil fields hard-to-recover oil reserves includes off low-permeability (less than 1-2 mD) and hyper-low-permeable (0.01-0.0001mD) fields. The latter in Russia include Bazhen, Domanic and Achimov fields. Their development provides for the mandatory completion of HW with Multiple-Fractured Horizontal Wells (MFHW). Experience in the development of layers of the specified type for Gazpromneft PJSC shows that the highest oil production rate is achieved if the MFHW system reveals not only the low-permeability rock matrix, but also captures the highly conductive (typically fractured) streaks — "strata-conveyors" (the latter may also be located in neighboring geological and stratigraphic differences). The difference in the permeability of such highly conductive layers and the hyper-low-permeable matrix of the host rocks can be very significant (up to 106!). In addition to the positive aspects of the presence of highly conductive layers in the section associated with the achievement of high initial oil flow rates in new wells, in the process of further development, negative consequences may arise as a result of premature (even unpredictable) gas and water breakthroughs through narrow fractured layers. Is it possible to take into account the risks of loss of well productivity as a consequence of the pronounced geological heterogeneity of these fields, even if the scale of the impact of this heterogeneity is still difficult to assess by modern research methods? In this paper analyzes some of the results of core, logging, well testing and indicator studies with the allocation of characteristic features indicating the presence of local highly conductive fractured layers in the section of the oil the Bazhen-Abalak complex (BAC).
{"title":"Highly Conductive Layers and their Role in the Development of Oil Fields of the Bazhen-Abalak Complex","authors":"A. Ipatov, E. Zhukovskaia, D. Lazutkin","doi":"10.2118/201814-ms","DOIUrl":"https://doi.org/10.2118/201814-ms","url":null,"abstract":"\u0000 Modern technology of drilling and construction of horizontal wells allows for effective development of complex oil fields hard-to-recover oil reserves includes off low-permeability (less than 1-2 mD) and hyper-low-permeable (0.01-0.0001mD) fields. The latter in Russia include Bazhen, Domanic and Achimov fields. Their development provides for the mandatory completion of HW with Multiple-Fractured Horizontal Wells (MFHW).\u0000 Experience in the development of layers of the specified type for Gazpromneft PJSC shows that the highest oil production rate is achieved if the MFHW system reveals not only the low-permeability rock matrix, but also captures the highly conductive (typically fractured) streaks — \"strata-conveyors\" (the latter may also be located in neighboring geological and stratigraphic differences). The difference in the permeability of such highly conductive layers and the hyper-low-permeable matrix of the host rocks can be very significant (up to 106!).\u0000 In addition to the positive aspects of the presence of highly conductive layers in the section associated with the achievement of high initial oil flow rates in new wells, in the process of further development, negative consequences may arise as a result of premature (even unpredictable) gas and water breakthroughs through narrow fractured layers. Is it possible to take into account the risks of loss of well productivity as a consequence of the pronounced geological heterogeneity of these fields, even if the scale of the impact of this heterogeneity is still difficult to assess by modern research methods?\u0000 In this paper analyzes some of the results of core, logging, well testing and indicator studies with the allocation of characteristic features indicating the presence of local highly conductive fractured layers in the section of the oil the Bazhen-Abalak complex (BAC).","PeriodicalId":359083,"journal":{"name":"Day 2 Tue, October 27, 2020","volume":"21 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122806923","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
V. Karpov, A. Ryazanov, N. Parshin, D. Sleptsov, D. Kashapov, K. Ovchinnikov, E. Malyavko, E. V. Potapova, A. Buyanov
Currently, there is a growing tendency to involve unconventionals in development, therefore drilling, completion and production stimulation technologies are being intensively developed. Cost-effective development of hard-to-recover reserves (HTR) is possible only with the involvement of horizontal drilling and multi-zone hydraulic fracturing. Due to the fact that conventional methods of PLT of horizontal wells for traditional reservoirs have a number of difficulties when operating on unconventionals, alternative methods for well surveying using flow indicators are increasingly in demand that allow multiphase monitoring of long-term multiphase inflow along a horizontal hole without involving additional equipment, well kill, etc. The objective of this article was to obtain confirmation on the profile distribution and inflow composition after the MSHF operation for further well intervention planning in the main unconventional of the Russian Federation – the Bazhenov formation. In a study, the inflow was monitored for oil and water phases in horizontal wells with multistage hydraulic fracturing (from 9 to 15 stages) and the use of the marked proppant. The technology of marker studies of horizontal wells consists in a single placement of high-precision indicators of fluid inflow in hydraulic fractures. After the completion of the MSHF field operation and putting the well into operation, sampling of the reservoir fluid from the wellhead was carried out and they were analyzed on the quantitative distribution of markers of each code corresponding to the interval distribution of oil and water flow rates. The monitoring of marked wells was carried out periodically for several months. The flow profiles of horizontal holes were constructed on the basis of analysis of samples and analytical data obtained. The results of the work allowed to analyze efficiency of stimulation of horizontal wells for each of the stages of hydraulic fracturing. Unlike traditional research methods, the main advantage of the presented technology for monitoring the horizontal inflow profile is the lack of need for using special means of device delivery, the use of the technology is not fraught with risks of seizure of equipment and ambiguity of interpretation. It is also important to note that this technology allows monitoring continuously for several years without additional measures. Comparison of research and monitoring methods is shown in table No. 1.Table No. 1.Comparison of the characteristics of various types of monitoring of well inflowsType of monitoringClassical set of PLT using CTDistributed fiber optic sensors for online monitoringMarked proppantMonitoring periodA few hoursUp to several years (depending on the quality of the optical material and the number of removal of solid particles from the rock)Hydrophilic, oleophilic, gas – more than 3 years (depending on conditions)The need to stop or change the well operation modeYesNoNoBench testsYesNoYesNumber of studies
{"title":"Dynamic Flow Monitoring in Horizontal Wells with High-Stage Mfrac in Conditions of Bazhen Formation","authors":"V. Karpov, A. Ryazanov, N. Parshin, D. Sleptsov, D. Kashapov, K. Ovchinnikov, E. Malyavko, E. V. Potapova, A. Buyanov","doi":"10.2118/202042-ms","DOIUrl":"https://doi.org/10.2118/202042-ms","url":null,"abstract":"\u0000 Currently, there is a growing tendency to involve unconventionals in development, therefore drilling, completion and production stimulation technologies are being intensively developed. Cost-effective development of hard-to-recover reserves (HTR) is possible only with the involvement of horizontal drilling and multi-zone hydraulic fracturing.\u0000 Due to the fact that conventional methods of PLT of horizontal wells for traditional reservoirs have a number of difficulties when operating on unconventionals, alternative methods for well surveying using flow indicators are increasingly in demand that allow multiphase monitoring of long-term multiphase inflow along a horizontal hole without involving additional equipment, well kill, etc.\u0000 The objective of this article was to obtain confirmation on the profile distribution and inflow composition after the MSHF operation for further well intervention planning in the main unconventional of the Russian Federation – the Bazhenov formation.\u0000 In a study, the inflow was monitored for oil and water phases in horizontal wells with multistage hydraulic fracturing (from 9 to 15 stages) and the use of the marked proppant. The technology of marker studies of horizontal wells consists in a single placement of high-precision indicators of fluid inflow in hydraulic fractures. After the completion of the MSHF field operation and putting the well into operation, sampling of the reservoir fluid from the wellhead was carried out and they were analyzed on the quantitative distribution of markers of each code corresponding to the interval distribution of oil and water flow rates.\u0000 The monitoring of marked wells was carried out periodically for several months. The flow profiles of horizontal holes were constructed on the basis of analysis of samples and analytical data obtained. The results of the work allowed to analyze efficiency of stimulation of horizontal wells for each of the stages of hydraulic fracturing.\u0000 Unlike traditional research methods, the main advantage of the presented technology for monitoring the horizontal inflow profile is the lack of need for using special means of device delivery, the use of the technology is not fraught with risks of seizure of equipment and ambiguity of interpretation. It is also important to note that this technology allows monitoring continuously for several years without additional measures.\u0000 Comparison of research and monitoring methods is shown in table No. 1.Table No. 1.Comparison of the characteristics of various types of monitoring of well inflowsType of monitoringClassical set of PLT using CTDistributed fiber optic sensors for online monitoringMarked proppantMonitoring periodA few hoursUp to several years (depending on the quality of the optical material and the number of removal of solid particles from the rock)Hydrophilic, oleophilic, gas – more than 3 years (depending on conditions)The need to stop or change the well operation modeYesNoNoBench testsYesNoYesNumber of studies","PeriodicalId":359083,"journal":{"name":"Day 2 Tue, October 27, 2020","volume":"74 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127375592","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 paper describes the results of application and prospects for the further implementation of simultaneous-separate operation equipment in slim hole wells and simultaneous-separate operation equipment for three development locations in wells of Territorial production enterprise «TatRITEKneft».
{"title":"Summary of Application Results and Prospects for the Further Implementation of Simultaneous-Separate Operation in Slim Hole Wells and Simultaneous-Separate Operation for Three Development Locations","authors":"A. Yakovlev","doi":"10.2118/201900-ms","DOIUrl":"https://doi.org/10.2118/201900-ms","url":null,"abstract":"\u0000 This paper describes the results of application and prospects for the further implementation of simultaneous-separate operation equipment in slim hole wells and simultaneous-separate operation equipment for three development locations in wells of Territorial production enterprise «TatRITEKneft».","PeriodicalId":359083,"journal":{"name":"Day 2 Tue, October 27, 2020","volume":"11 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127929094","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}
T. Solovyev, A. Ivanov, Dzheykhun Soltanov, V. Meshkov, A. Kamalov, V. Nagimov, A. Trusov, I. Aslanyan, D. Makarov
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":"Smart Completion Improvement in Horizontal Wells Based on Through-Barrier Diagnostics","authors":"T. Solovyev, A. Ivanov, Dzheykhun Soltanov, V. Meshkov, A. Kamalov, V. Nagimov, A. Trusov, I. Aslanyan, D. Makarov","doi":"10.2118/201896-ms","DOIUrl":"https://doi.org/10.2118/201896-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":359083,"journal":{"name":"Day 2 Tue, October 27, 2020","volume":"86 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-10-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114320761","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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