T. Koshkin, Azat Firdavisovich Sayfutdinov, Viktor Aleksandrovich Kukushkin, Pavel Vladimirovich Markov
The article reviews the development and implementation of a digital twin for one of the large fields of LUKOIL-West Siberia LLC. The project team has developed an integrated asset model (IAM) of an oil field at a late stage of its development, which is used both for making managerial decisions and in the operational work of the engineering and technical service. The IAM includes simplified models of reservoirs, models of wells and gathering systems, as well as simplified models of plants. The resulting model can produce short-term assumptions regarding production levels (up to 1 year) and is highly sustainable, which is confirmed by the examples given in this article as to the application of IAM for various production tasks. The developed automated tools allow making prompt decisions to optimize well stock operation, as well as to reveal deviations in the process parameters of downhole pumping equipment and metering facilities. The use of IAM tools enable production functions to perform many application tasks related to forecasting well operation modes and evaluating the existing production capacities of the field. The cases presented in this paper serve as a good practice for application of the IM by assets in their activities and can be implemented for similar brownfields.
{"title":"Application of Integrated Asset Modeling Approaches for Reservoir Management of a Large Oil Field in Western Siberia","authors":"T. Koshkin, Azat Firdavisovich Sayfutdinov, Viktor Aleksandrovich Kukushkin, Pavel Vladimirovich Markov","doi":"10.2118/206538-ms","DOIUrl":"https://doi.org/10.2118/206538-ms","url":null,"abstract":"\u0000 The article reviews the development and implementation of a digital twin for one of the large fields of LUKOIL-West Siberia LLC. The project team has developed an integrated asset model (IAM) of an oil field at a late stage of its development, which is used both for making managerial decisions and in the operational work of the engineering and technical service. The IAM includes simplified models of reservoirs, models of wells and gathering systems, as well as simplified models of plants. The resulting model can produce short-term assumptions regarding production levels (up to 1 year) and is highly sustainable, which is confirmed by the examples given in this article as to the application of IAM for various production tasks. The developed automated tools allow making prompt decisions to optimize well stock operation, as well as to reveal deviations in the process parameters of downhole pumping equipment and metering facilities. The use of IAM tools enable production functions to perform many application tasks related to forecasting well operation modes and evaluating the existing production capacities of the field. The cases presented in this paper serve as a good practice for application of the IM by assets in their activities and can be implemented for similar brownfields.","PeriodicalId":10970,"journal":{"name":"Day 1 Tue, October 12, 2021","volume":"24 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80145144","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.. Sherishorin, M. Rylance, Yevgeniy V. Tuzov, O. Krokhaleva, E. Tikhonov, Oleg Chirkov, Ruslan Ivanov
The paper describes the first deployment of HGS in Eastern Siberia as a mud additive. The technology was utilized for reducing drilling fluid density for prevention and mitigation of losses; while drilling through a producing reservoir section with low pore pressure, unconsolidated and fractured sands. The engineering considerations, fundamentals of the approach and major risks involved were reviewed with application to the Sredneboutobinskoye Oilfield as a pilot field application for broader future plans. Key planning, delivery and execution principles of the initial application will be reported in the paper. Initially deployed on three wells, including multi-laterals (Rylance et al., 2021), the paper will walk through the engineering considerations during the planning and execution phases. Key sections include the data gathered and the many lessons learned during the incremental and stepwise deployment. The paper will also report on post drilling productivity and comparisons with the offset wells drilled with conventional mud systems, which suffered severe losses. The results of this pilot have exceeded expectations. There have been many insights and the Team are now looking to set a timetable to scale-up across the Taas-Yuryakh Neftegazodobycha (TYNGD). After many hours of laboratories study and preparation works, the general plan was to reduce the static density and ECD to mitigate fluid losses. However, the applied results showed additional effects from HGS. Data will be provided that demonstrated loss-free drilling was achieved where this had not been the case before, with a material reduction in NPT, lost circulation material (LCM) needs and costs. Much has been learned, recovered HGS material has been demonstrated to be an effective LCM pill and centralization of mud processing may offer additional cost savings and improvements. Further efficiencies are also expected to be achieved and future potential is considerable. HGS for cementing is well documented, yet application for drilling fluids has been less well reported and almost exclusively related to single wells. The TYNGD application is innovative as this is a major development with 10 active drilling rigs. The application is on multi-laterals and offset wells are available for direct comparison. The results of the approach demonstrate a new way of performing well construction in an effective manner for major field developments where losses are prevalent.
{"title":"Hollow Glass Spheres HGS in Drilling Fluid: Case Study of Preventing and Mitigating Total Losses","authors":"V.. Sherishorin, M. Rylance, Yevgeniy V. Tuzov, O. Krokhaleva, E. Tikhonov, Oleg Chirkov, Ruslan Ivanov","doi":"10.2118/206447-ms","DOIUrl":"https://doi.org/10.2118/206447-ms","url":null,"abstract":"\u0000 The paper describes the first deployment of HGS in Eastern Siberia as a mud additive. The technology was utilized for reducing drilling fluid density for prevention and mitigation of losses; while drilling through a producing reservoir section with low pore pressure, unconsolidated and fractured sands. The engineering considerations, fundamentals of the approach and major risks involved were reviewed with application to the Sredneboutobinskoye Oilfield as a pilot field application for broader future plans.\u0000 Key planning, delivery and execution principles of the initial application will be reported in the paper. Initially deployed on three wells, including multi-laterals (Rylance et al., 2021), the paper will walk through the engineering considerations during the planning and execution phases. Key sections include the data gathered and the many lessons learned during the incremental and stepwise deployment. The paper will also report on post drilling productivity and comparisons with the offset wells drilled with conventional mud systems, which suffered severe losses.\u0000 The results of this pilot have exceeded expectations. There have been many insights and the Team are now looking to set a timetable to scale-up across the Taas-Yuryakh Neftegazodobycha (TYNGD). After many hours of laboratories study and preparation works, the general plan was to reduce the static density and ECD to mitigate fluid losses. However, the applied results showed additional effects from HGS. Data will be provided that demonstrated loss-free drilling was achieved where this had not been the case before, with a material reduction in NPT, lost circulation material (LCM) needs and costs. Much has been learned, recovered HGS material has been demonstrated to be an effective LCM pill and centralization of mud processing may offer additional cost savings and improvements. Further efficiencies are also expected to be achieved and future potential is considerable.\u0000 HGS for cementing is well documented, yet application for drilling fluids has been less well reported and almost exclusively related to single wells. The TYNGD application is innovative as this is a major development with 10 active drilling rigs. The application is on multi-laterals and offset wells are available for direct comparison. The results of the approach demonstrate a new way of performing well construction in an effective manner for major field developments where losses are prevalent.","PeriodicalId":10970,"journal":{"name":"Day 1 Tue, October 12, 2021","volume":"128 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77756374","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}
B. Ganiev, A. Lutfullin, I. Karimov, Rinat Shaydullin, V. Nagimov, M. Volkov, A. Vdovin, A. Trusov, A. Sviridov, A. Elkadi
The paper presents a new technology for the oil and gas industry for azimuthal electromagnetic scanning of the first tubular wall defects, the basis of which is a small-sized sector scanning tool that measures the pipe wall thickness. The paper presents the results of laboratoryand well tests, as well as the early field surveys using this technology. These constitute thebasis on which the actual sensitivity of the technology and its prospects in diagnosing well integrity are determined.
{"title":"Sectorial Scanning Electromagnetic Defectoscope: The Next Stage in Well Integrity Diagnostics","authors":"B. Ganiev, A. Lutfullin, I. Karimov, Rinat Shaydullin, V. Nagimov, M. Volkov, A. Vdovin, A. Trusov, A. Sviridov, A. Elkadi","doi":"10.2118/206630-ms","DOIUrl":"https://doi.org/10.2118/206630-ms","url":null,"abstract":"\u0000 The paper presents a new technology for the oil and gas industry for azimuthal electromagnetic scanning of the first tubular wall defects, the basis of which is a small-sized sector scanning tool that measures the pipe wall thickness. The paper presents the results of laboratoryand well tests, as well as the early field surveys using this technology. These constitute thebasis on which the actual sensitivity of the technology and its prospects in diagnosing well integrity are determined.","PeriodicalId":10970,"journal":{"name":"Day 1 Tue, October 12, 2021","volume":"19 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86210785","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 Capacitance Resistance Model (CRM) is an analytical model that only requires production and injection rates to predict reservoir performance. The CRM input is the injection rates and the output is the production rate. The input and output are related by the CRM parameters. The first parameter is the time delay (also called time constant) and is a function of pore volume, total compressibility, and productivity indices. The second parameter is the connectivity (also called gain, or weight), which quantifies the connectivity between producers and injectors (i.e. how much of the input is supporting the output). The CRM was developed for fields with minimum reservoir data, or for small fields not requiring a full reservoir simulation model, which can be time-consuming and expensive. The CRM is a quick, powerful analytical tool that is simple to use and requires readily available data. Most of the time, the injection and production rates are measured accurately and frequently, either weekly or bi-weekly. By solving the continuity equation for a homogenous reservoir (i.e. constant reservoir and fluid properties throughout the reservoir) the solution of the continuity equation can be indicative of the injection and production relation and therefore can be used to optimize injection schemes for higher ultimate hydrocarbon recovery. It is important to recognize that the CRM is not supposed to replace numerical reservoir simulators, which, in essence, are the most accurate means of reservoir performance prediction. Instead, the CRM aims to be a quick and easy way to infer reservoir performance in the absence of full-fledged simulation. The CRM has been used for several purposes as seen in the literature. First, as a tool to optimize waterflooding in oil reservoirs. The CRM can infer inter-well connectivity which will allow the engineer to adjust water injection rates to ensure uniform sweep in the reservoir and reduce the chance of early water breakthrough. The CRM was also used to optimize CO2 sequestration, whereby CO¬2 is captured from the atmosphere and stored in subsurface formations. The main hypothesis in CRM is that the characteristics of the reservoir can be inferred from analyzing production and injection data only. CRM does not require core data, logs, seismic, or any rock or fluids properties. This hypothesis can be challenged easily since most reservoirs have gradients of fluid properties, multi-porosity systems, and heterogeneous formations with different wettability presences. Albeit, several publications have shown that CRM can result in high certainty output. The objective of this report is to explain the concept of the CRM, conduct a critical review of the main CRM publications, compare CRM to other reservoir characterization tools and finally demonstrate some applications of the CRM.
{"title":"A Critical Review of Capacitance-Resistance Models","authors":"A. Alghamdi, Moaz Hiba, M. Aly, A. Awotunde","doi":"10.2118/206555-ms","DOIUrl":"https://doi.org/10.2118/206555-ms","url":null,"abstract":"\u0000 A Capacitance Resistance Model (CRM) is an analytical model that only requires production and injection rates to predict reservoir performance. The CRM input is the injection rates and the output is the production rate. The input and output are related by the CRM parameters. The first parameter is the time delay (also called time constant) and is a function of pore volume, total compressibility, and productivity indices. The second parameter is the connectivity (also called gain, or weight), which quantifies the connectivity between producers and injectors (i.e. how much of the input is supporting the output).\u0000 The CRM was developed for fields with minimum reservoir data, or for small fields not requiring a full reservoir simulation model, which can be time-consuming and expensive. The CRM is a quick, powerful analytical tool that is simple to use and requires readily available data. Most of the time, the injection and production rates are measured accurately and frequently, either weekly or bi-weekly. By solving the continuity equation for a homogenous reservoir (i.e. constant reservoir and fluid properties throughout the reservoir) the solution of the continuity equation can be indicative of the injection and production relation and therefore can be used to optimize injection schemes for higher ultimate hydrocarbon recovery. It is important to recognize that the CRM is not supposed to replace numerical reservoir simulators, which, in essence, are the most accurate means of reservoir performance prediction. Instead, the CRM aims to be a quick and easy way to infer reservoir performance in the absence of full-fledged simulation.\u0000 The CRM has been used for several purposes as seen in the literature. First, as a tool to optimize waterflooding in oil reservoirs. The CRM can infer inter-well connectivity which will allow the engineer to adjust water injection rates to ensure uniform sweep in the reservoir and reduce the chance of early water breakthrough. The CRM was also used to optimize CO2 sequestration, whereby CO¬2 is captured from the atmosphere and stored in subsurface formations.\u0000 The main hypothesis in CRM is that the characteristics of the reservoir can be inferred from analyzing production and injection data only. CRM does not require core data, logs, seismic, or any rock or fluids properties. This hypothesis can be challenged easily since most reservoirs have gradients of fluid properties, multi-porosity systems, and heterogeneous formations with different wettability presences. Albeit, several publications have shown that CRM can result in high certainty output.\u0000 The objective of this report is to explain the concept of the CRM, conduct a critical review of the main CRM publications, compare CRM to other reservoir characterization tools and finally demonstrate some applications of the CRM.","PeriodicalId":10970,"journal":{"name":"Day 1 Tue, October 12, 2021","volume":"40 5 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82844731","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}
Fractured carbonate formations around the world are prone to lost circulation that not only affects the well construction process but creating a longtime effect on the wellbore integrity. Despite multiple attempts to cure them the success rate is usually low. This manuscript is aiming to provide a new vision on the reason of lost circulation across carbonates. To have better understanding of the complete losses across the fractured carbonates the series of studies were initiated. At first to understand the strength of the loss zone the fracture closing pressure was evaluated via study of the fluid level in the annulus and back-calculation of the drilling fluid density effect on it. Secondary, the rock properties across the loss circulation zones were studied by using the microresistivity images, dip data, and imaging of fluid-saturated porous media. At last, the trial tests with different treatment materials were performed to evaluate the effect of it on curing the losses. The results of the studies brought new information and explained some previous unknowns. The formation strength across lost circulation zone was measured and it was confirmed to remain constant despite other changes of the well conduction parameters. It was also confirmed that the carbonates are naturally highly fractured having over 900 fractures along the wellbore. The lost circulation zone was characterized, and it was confirmed that the losses were not related to the fractures but rather to the karst, dissolution and to mega-fractures. The size and dip of the fractures were identified, and it was proven the possibility to treat them with conventional materials. However, the size of identified mega-fractures and karst zones exceed the fractures by 100 times in true vertical depth, and in horizontal wells the difference is thousands times due to measured depth. This new information explains the previous unsuccessful attempts with the conventional lost circulation materials. Further based on the newly available information the mathematic description of the lost circulation zones was provided.
{"title":"Quantification of the Loss Conduit Aperture During Lost Circulation in Fractured Carbonates","authors":"A. Ruzhnikov, Ashley Johnson","doi":"10.2118/206446-ms","DOIUrl":"https://doi.org/10.2118/206446-ms","url":null,"abstract":"\u0000 Fractured carbonate formations around the world are prone to lost circulation that not only affects the well construction process but creating a longtime effect on the wellbore integrity. Despite multiple attempts to cure them the success rate is usually low. This manuscript is aiming to provide a new vision on the reason of lost circulation across carbonates.\u0000 To have better understanding of the complete losses across the fractured carbonates the series of studies were initiated. At first to understand the strength of the loss zone the fracture closing pressure was evaluated via study of the fluid level in the annulus and back-calculation of the drilling fluid density effect on it. Secondary, the rock properties across the loss circulation zones were studied by using the microresistivity images, dip data, and imaging of fluid-saturated porous media. At last, the trial tests with different treatment materials were performed to evaluate the effect of it on curing the losses.\u0000 The results of the studies brought new information and explained some previous unknowns. The formation strength across lost circulation zone was measured and it was confirmed to remain constant despite other changes of the well conduction parameters. It was also confirmed that the carbonates are naturally highly fractured having over 900 fractures along the wellbore. The lost circulation zone was characterized, and it was confirmed that the losses were not related to the fractures but rather to the karst, dissolution and to mega-fractures. The size and dip of the fractures were identified, and it was proven the possibility to treat them with conventional materials. However, the size of identified mega-fractures and karst zones exceed the fractures by 100 times in true vertical depth, and in horizontal wells the difference is thousands times due to measured depth. This new information explains the previous unsuccessful attempts with the conventional lost circulation materials. Further based on the newly available information the mathematic description of the lost circulation zones was provided.","PeriodicalId":10970,"journal":{"name":"Day 1 Tue, October 12, 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":"83670666","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}
Andrey Garipov, Andrey Aleksandrovich Rebrikov, A. Galimkhanov, A. Mikhaylov, Almaz Khalilov, Denis Sergeevich Kochetkov, D. Tur, Aleksandr Aleksandrovich Yavorsky, Vladimir Aleksandrovich Maltsev, A. Rybalkin, V. Pogurets, Viktor Vyacheslavovich Zolotenkov, D. Levitskiy
This article is a description of a comprehensive engineering approach to new designs of PDC (Polycrystalline Diamond Compact) Bits and bottomhole equipment for efficient horizontal wells drilling in the Yamal-Nenets Autonomous Okrug (YNAO) fields with Rotary Steerable Systems (RSS) Point the Bit (PTB) type. The paper represents an analysis of the efficiency of drilling rocks of various hardness depending on the bits, the bottom hole assembly (BHA), and type of vibrations. In the Yamal region fields a main constraint of sub horizontal sections drilling performance for liner run in hole is the occurrence of vibrations. The predominant vibration types are Stick and Slip (S&S) and High Frequency Torsional Oscillations (HFTO). These types of vibrations often had to be reduced by limiting drilling regime (weight on bit (WOB), drill pipe (DP) RPM, and flow rate), which directly affected on the rate of penetration (ROP). To find solutions to this problem for drilling performance improvement, geological and geomechanically modeling of rock properties and an analysis of burst-files of vibrations (modeled in specialized software) were carried out based on downhole data. The studies have found key factors that cause the high vibration impact and reasons for premature wear of the PDC bits, which served as a basis for identifying the shortcomings of previous bit designs. Test beam experiments were also performed to assess the bits wear while drill-out of the casing accessories. The results formed the basis for development of new PDC bits designs using specialized software. As an output new 155.6/152.4 mm bits designs with an innovative cutting structure that considers the geological features and technical aspects of drilling liner sections in YNAO fields were manufactured. The new bit designs have significantly reduced vibration levels, improved ROP performance in the liner section using RSS PTB, and decreased the overall well construction time. These solutions open wide opportunities for their further implementation on other projects both in Russia and in other CIS countries.
{"title":"Efficient PDC Bit Designs Reduced Vibrational Impact While Drilling with Rotary Steerable Systems in the Geological Conditions of the Yamalo-Nenets Autonomous District","authors":"Andrey Garipov, Andrey Aleksandrovich Rebrikov, A. Galimkhanov, A. Mikhaylov, Almaz Khalilov, Denis Sergeevich Kochetkov, D. Tur, Aleksandr Aleksandrovich Yavorsky, Vladimir Aleksandrovich Maltsev, A. Rybalkin, V. Pogurets, Viktor Vyacheslavovich Zolotenkov, D. Levitskiy","doi":"10.2118/206460-ms","DOIUrl":"https://doi.org/10.2118/206460-ms","url":null,"abstract":"\u0000 This article is a description of a comprehensive engineering approach to new designs of PDC (Polycrystalline Diamond Compact) Bits and bottomhole equipment for efficient horizontal wells drilling in the Yamal-Nenets Autonomous Okrug (YNAO) fields with Rotary Steerable Systems (RSS) Point the Bit (PTB) type. The paper represents an analysis of the efficiency of drilling rocks of various hardness depending on the bits, the bottom hole assembly (BHA), and type of vibrations.\u0000 In the Yamal region fields a main constraint of sub horizontal sections drilling performance for liner run in hole is the occurrence of vibrations. The predominant vibration types are Stick and Slip (S&S) and High Frequency Torsional Oscillations (HFTO). These types of vibrations often had to be reduced by limiting drilling regime (weight on bit (WOB), drill pipe (DP) RPM, and flow rate), which directly affected on the rate of penetration (ROP).\u0000 To find solutions to this problem for drilling performance improvement, geological and geomechanically modeling of rock properties and an analysis of burst-files of vibrations (modeled in specialized software) were carried out based on downhole data. The studies have found key factors that cause the high vibration impact and reasons for premature wear of the PDC bits, which served as a basis for identifying the shortcomings of previous bit designs. Test beam experiments were also performed to assess the bits wear while drill-out of the casing accessories. The results formed the basis for development of new PDC bits designs using specialized software.\u0000 As an output new 155.6/152.4 mm bits designs with an innovative cutting structure that considers the geological features and technical aspects of drilling liner sections in YNAO fields were manufactured.\u0000 The new bit designs have significantly reduced vibration levels, improved ROP performance in the liner section using RSS PTB, and decreased the overall well construction time. These solutions open wide opportunities for their further implementation on other projects both in Russia and in other CIS countries.","PeriodicalId":10970,"journal":{"name":"Day 1 Tue, October 12, 2021","volume":"24 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78655852","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}
Makpal Bektybayeva, N. Mendybaev, Asfandiyar Bigeldiyev, S. Basu, A. Abetov, Aidos Temirkhassov, Ranida Tyulebayeva, Aiyazhan Yermukhanbet
For accurate coal bed methane (CBM) reserves estimation, it is necessary to evaluate reservoir characteristics. We present a workflow for formation evaluation of coalbed-methane wells, by interpretation of a limited number of legacy logs, including data preprocessing, lithology identification, proximate analysis and estimation of gas content of coal beds. This workflow allowed the estimation of ash content from the available logs, including selective log (analogue of photoelectric absorption), which was recorded only on the territory of the former Soviet Union and never used for such calculations before. Even though the logs were recorded by old tools with low vertical resolution, we were able to identify heterogeneity of coal seams, using the principle of core ash content distribution. Integrated analysis of old core data and recent laboratory measurements of samples from coal pillars allowed to calculate proximate properties of the coal, which showed good match with observed data and could be considered as input parameters for property distribution in the geological model. Also, it is worth to mention that an advanced plug-in was deployed to perform calculation of proximate properties and gas content for all available options and to significantly reduce time for screening different algorithms and rapidly analyzing results.
{"title":"Workflow of Petrophysical Analysis Performed at Mine in Karaganda Coal Basin","authors":"Makpal Bektybayeva, N. Mendybaev, Asfandiyar Bigeldiyev, S. Basu, A. Abetov, Aidos Temirkhassov, Ranida Tyulebayeva, Aiyazhan Yermukhanbet","doi":"10.2118/206627-ms","DOIUrl":"https://doi.org/10.2118/206627-ms","url":null,"abstract":"\u0000 For accurate coal bed methane (CBM) reserves estimation, it is necessary to evaluate reservoir characteristics. We present a workflow for formation evaluation of coalbed-methane wells, by interpretation of a limited number of legacy logs, including data preprocessing, lithology identification, proximate analysis and estimation of gas content of coal beds.\u0000 This workflow allowed the estimation of ash content from the available logs, including selective log (analogue of photoelectric absorption), which was recorded only on the territory of the former Soviet Union and never used for such calculations before. Even though the logs were recorded by old tools with low vertical resolution, we were able to identify heterogeneity of coal seams, using the principle of core ash content distribution. Integrated analysis of old core data and recent laboratory measurements of samples from coal pillars allowed to calculate proximate properties of the coal, which showed good match with observed data and could be considered as input parameters for property distribution in the geological model.\u0000 Also, it is worth to mention that an advanced plug-in was deployed to perform calculation of proximate properties and gas content for all available options and to significantly reduce time for screening different algorithms and rapidly analyzing results.","PeriodicalId":10970,"journal":{"name":"Day 1 Tue, October 12, 2021","volume":"57 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80912836","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}
Drilling is traditionally considered as one of the most challenging and expensive areas in oil and gas industry, and its efficiency, against the background with the of unstable forecast in current situation with growing oil prices, both defines the efficiency of capital investments at well construction stage and the cost of production as a whole. Changing drilling conditions, such as well depths, their complicated architectures due to reservoir depletion and their complex localization conditions, pose the task of attracting advanced technologies aimed at modifying the labor process, reduction in costs and increase in production efficiency ("GazpromNeft", 2015). However, not all such procedures are mass-produced due to high price that you need to pay for them, as well as possible limitations of obtaining these technologies. There is a need to implement the tasks in short term with the available resources without involving any expensive equipment and additional personnel (Litvinenko et al., 2017). This opportunity is opened by effective data management in the progress of well construction as well as in information and analytical supporting tools that allow you to receive, process and control this data in a short time and to take the appropriate management decisions based on it (Ivanov, 2017). Of course, one of the foundations in the controlling over the industrial processes is the reference book of time standards to perform basic operations in drilling and casing the wells (Unified Time Regulations in Process, 1987), which is mainly aimed at preventing unjustified costs during the process of well construction (excess time), planning the duration of operations, conducting procedures to select the applicants for work.
钻井一直被认为是油气行业中最具挑战性和最昂贵的领域之一，在当前油价不断上涨的情况下，钻井效率在预测不稳定的背景下，既决定了建井阶段资本投资的效率，也决定了整体生产成本。不断变化的钻井条件，如井深，由于油藏枯竭而导致的复杂结构以及复杂的定位条件，提出了吸引先进技术的任务，旨在改变劳动过程，降低成本和提高生产效率(“GazpromNeft”，2015)。然而，并非所有这些程序都是大规模生产的，因为你需要为它们支付高昂的价格，以及获得这些技术的可能限制。有必要在不涉及任何昂贵设备和额外人员的情况下，利用现有资源在短期内实施这些任务(Litvinenko et al.， 2017)。通过有效的数据管理，以及信息和分析支持工具，可以在短时间内接收、处理和控制这些数据，并根据这些数据做出适当的管理决策，从而打开了这一机会(Ivanov, 2017)。当然，控制工业过程的基础之一是执行钻井和套管基本操作的时间标准参考书(统一时间规则过程，1987年)，其主要目的是防止在建井过程中不合理的成本(超时)，计划作业持续时间，进行程序选择工作申请人。
{"title":"Analytical Resources of Digital Procedures in Monitoring and Controlling the Processes in Drilling the Wells","authors":"V. Kozhin, Aleksey Anatolevich Patorov, Evgeniy Alekseevich Lunin, Kamil Rafikovich Davletov","doi":"10.2118/206464-ms","DOIUrl":"https://doi.org/10.2118/206464-ms","url":null,"abstract":"\u0000 Drilling is traditionally considered as one of the most challenging and expensive areas in oil and gas industry, and its efficiency, against the background with the of unstable forecast in current situation with growing oil prices, both defines the efficiency of capital investments at well construction stage and the cost of production as a whole. Changing drilling conditions, such as well depths, their complicated architectures due to reservoir depletion and their complex localization conditions, pose the task of attracting advanced technologies aimed at modifying the labor process, reduction in costs and increase in production efficiency (\"GazpromNeft\", 2015). However, not all such procedures are mass-produced due to high price that you need to pay for them, as well as possible limitations of obtaining these technologies. There is a need to implement the tasks in short term with the available resources without involving any expensive equipment and additional personnel (Litvinenko et al., 2017). This opportunity is opened by effective data management in the progress of well construction as well as in information and analytical supporting tools that allow you to receive, process and control this data in a short time and to take the appropriate management decisions based on it (Ivanov, 2017).\u0000 Of course, one of the foundations in the controlling over the industrial processes is the reference book of time standards to perform basic operations in drilling and casing the wells (Unified Time Regulations in Process, 1987), which is mainly aimed at preventing unjustified costs during the process of well construction (excess time), planning the duration of operations, conducting procedures to select the applicants for work.","PeriodicalId":10970,"journal":{"name":"Day 1 Tue, October 12, 2021","volume":"25 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81041585","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. Bogachev, Aleksandr Zagainov, E. Piskovskiy, Iuliia Moshina, Aleksei Grishin, Anton Muryzhnikov, Aydar Gatin, N. Korostelev
The creation and matching of an integrated field model including a model for part of a giant field, well models and surface network model is considered here. The integrated model was created using an innovative method of solving a unified system of equations that cover all the physical processes in the reservoir-well-surface network system; no integrator software was involved. The project involves a history-matched dynamic model covering part of a giant field, a surface network layout and well constructions with the subsurface equipment parameters. These data were fed to a single software product to create a digital twin which would allow simultaneous work with both the reservoir and the network. The approach enabled quick creation and matching of an integrated model with a lot of wells which can create forecasts for various operation modes and estimate the base case production for the infrastructure in place, as well as offers an option to connect new project wells to the current surface network.
{"title":"Integrated Field Development Modeling of Block in Giant Oil Reservoir","authors":"K. Bogachev, Aleksandr Zagainov, E. Piskovskiy, Iuliia Moshina, Aleksei Grishin, Anton Muryzhnikov, Aydar Gatin, N. Korostelev","doi":"10.2118/206539-ms","DOIUrl":"https://doi.org/10.2118/206539-ms","url":null,"abstract":"\u0000 The creation and matching of an integrated field model including a model for part of a giant field, well models and surface network model is considered here.\u0000 The integrated model was created using an innovative method of solving a unified system of equations that cover all the physical processes in the reservoir-well-surface network system; no integrator software was involved.\u0000 The project involves a history-matched dynamic model covering part of a giant field, a surface network layout and well constructions with the subsurface equipment parameters. These data were fed to a single software product to create a digital twin which would allow simultaneous work with both the reservoir and the network.\u0000 The approach enabled quick creation and matching of an integrated model with a lot of wells which can create forecasts for various operation modes and estimate the base case production for the infrastructure in place, as well as offers an option to connect new project wells to the current surface network.","PeriodicalId":10970,"journal":{"name":"Day 1 Tue, October 12, 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":"81979912","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. V. Fomenkov, Ilya Pinigin, Mikhail Tsibulsky, Dmitry Yurievich Terentyev, Artem Alexandrovich Fedyanin
This article describes the application of relatively high-density foamed cement for cementing wells in the Volga and Urals region. Good cementing practices with high density or conventional density cement slurry is required to ensure mud displacement in fluid saturated intervals of reservoir formations (Benge et al; 1982). With this requirement met, the cement column should circumferentially cover the annulus at this very interval which is exposed to the highest loads. However, due to limited physical and mechanical properties of conventional cement slurries in both liquid and solid state, in certain cases conventional slurries do not solve the problems encountered by the Customer, namely elimination of annular flow between the casing and cement sheath. High-density foamed cement is considered as an improved alternative to conventional cement slurries, and results in a high quality and durable sealing of gas and oil saturated production zones for the life of the well. Proprietary software and process equipment are used for the mixing of the foamed cement slurry with a variety of foaming properties. This process enables the use of a base cement slurry with higher density (up to 2.1 g/cm3) for delivering foamed cement slurries in a wide range of densities. To avoid possible cross flows behind the casing, pilot tests were conducted, where a conventional cement slurry (1.80–1.90 g/cm3) was replaced with a high-density foamed cement slurry with equivalent density with a foam quality of approx. 10% making the cement sheath elastic with improved adhesion to both the casing string and the formation (Spaulding et al; 2018). Pilot tests, incorporating the cementing of several production casings, were conducted where only foamed cement slurries with various foam quality were used in the entire cementing interval. No conventional (non-foamed) cement systems were used in these cases.
{"title":"High Density Foamed Cement Application for Channeling and Behind-the-Casing Flows Minimization in the Production Zone","authors":"A. V. Fomenkov, Ilya Pinigin, Mikhail Tsibulsky, Dmitry Yurievich Terentyev, Artem Alexandrovich Fedyanin","doi":"10.2118/206442-ms","DOIUrl":"https://doi.org/10.2118/206442-ms","url":null,"abstract":"\u0000 This article describes the application of relatively high-density foamed cement for cementing wells in the Volga and Urals region. Good cementing practices with high density or conventional density cement slurry is required to ensure mud displacement in fluid saturated intervals of reservoir formations (Benge et al; 1982). With this requirement met, the cement column should circumferentially cover the annulus at this very interval which is exposed to the highest loads. However, due to limited physical and mechanical properties of conventional cement slurries in both liquid and solid state, in certain cases conventional slurries do not solve the problems encountered by the Customer, namely elimination of annular flow between the casing and cement sheath. High-density foamed cement is considered as an improved alternative to conventional cement slurries, and results in a high quality and durable sealing of gas and oil saturated production zones for the life of the well.\u0000 Proprietary software and process equipment are used for the mixing of the foamed cement slurry with a variety of foaming properties. This process enables the use of a base cement slurry with higher density (up to 2.1 g/cm3) for delivering foamed cement slurries in a wide range of densities. To avoid possible cross flows behind the casing, pilot tests were conducted, where a conventional cement slurry (1.80–1.90 g/cm3) was replaced with a high-density foamed cement slurry with equivalent density with a foam quality of approx. 10% making the cement sheath elastic with improved adhesion to both the casing string and the formation (Spaulding et al; 2018). Pilot tests, incorporating the cementing of several production casings, were conducted where only foamed cement slurries with various foam quality were used in the entire cementing interval. No conventional (non-foamed) cement systems were used in these cases.","PeriodicalId":10970,"journal":{"name":"Day 1 Tue, October 12, 2021","volume":"10 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80168783","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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