D.К. Lobastov, Svetlana Nafikova, I. Akhmetzianov, Sh. G. Zaripov, D. Krivolapov
The collaborative approach used for cementing the production liner in an onshore development well in Russia is presented. The reservoir has a narrow window between pore and fracture pressures, which has previously caused formation instability and severe lost circulation issues during well construction, compromising zonal isolation objectives. Total loss of fluids experienced while cementing the 114.3 mm production liner in the first appraisal well in the field led to revising the cementing strategy. Collaboration among various parts of the drilling department and the opportunity to define a new approach resulted in a decision to introduce managed pressure drilling (MPD) to address the challenges associated with a narrow pressure window and uncertainty in pore pressure while drilling and cementing. This enabled implementing the optimal mud weight and adjusting equivalent circulating density (ECD) during cementing with minimum overbalance. Reducing the mud weight from 1.20 SG to 1.05 SG eliminated losses after running the liner and while cementing it. As a result, pre-job circulation rates and pumping rates during cementing could be increased, improving mud removal efficiency and achieving top of cement at the required depth. The constant-bottomhole-pressure mode of MPD was used to maintain the same ECD during displacement of the well to a lighter fluid and during cementing, avoiding well influx during pumpoff events by compensating for the annular friction pressure loss with surface backpressure. This first onshore managed pressure cementing operation executed within the same field in Russia (later named as field A) was completed flawlessly, with no safety or quality issues, zero nonproductive time, and achievement of the required zonal isolation across the challenging production section. The collaborative approach used was a novel strategy, with the mud weight program strategically adjusted before and during the cementing operation to achieve zonal isolation objectives.
{"title":"Collaborative Approach Overcomes Cementing Challenges in Narrow Pressure Window Environment","authors":"D.К. Lobastov, Svetlana Nafikova, I. Akhmetzianov, Sh. G. Zaripov, D. Krivolapov","doi":"10.2118/206443-ms","DOIUrl":"https://doi.org/10.2118/206443-ms","url":null,"abstract":"\u0000 The collaborative approach used for cementing the production liner in an onshore development well in Russia is presented. The reservoir has a narrow window between pore and fracture pressures, which has previously caused formation instability and severe lost circulation issues during well construction, compromising zonal isolation objectives.\u0000 Total loss of fluids experienced while cementing the 114.3 mm production liner in the first appraisal well in the field led to revising the cementing strategy. Collaboration among various parts of the drilling department and the opportunity to define a new approach resulted in a decision to introduce managed pressure drilling (MPD) to address the challenges associated with a narrow pressure window and uncertainty in pore pressure while drilling and cementing. This enabled implementing the optimal mud weight and adjusting equivalent circulating density (ECD) during cementing with minimum overbalance.\u0000 Reducing the mud weight from 1.20 SG to 1.05 SG eliminated losses after running the liner and while cementing it. As a result, pre-job circulation rates and pumping rates during cementing could be increased, improving mud removal efficiency and achieving top of cement at the required depth. The constant-bottomhole-pressure mode of MPD was used to maintain the same ECD during displacement of the well to a lighter fluid and during cementing, avoiding well influx during pumpoff events by compensating for the annular friction pressure loss with surface backpressure. This first onshore managed pressure cementing operation executed within the same field in Russia (later named as field A) was completed flawlessly, with no safety or quality issues, zero nonproductive time, and achievement of the required zonal isolation across the challenging production section.\u0000 The collaborative approach used was a novel strategy, with the mud weight program strategically adjusted before and during the cementing operation to achieve zonal isolation objectives.","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":"87382257","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. Sharafutdinov, R. Valiullin, D. Kosmylin, Ayrat Ramazanov, Vladimir Fedotov, V. V. Bajenov, A. I. Imaev
The paper considers two approaches based on the use of an induction heater: the first is a "large thermal anemometer", in which the casing is heated by induction action and the problem of determining column flows, determining the flow rate and the inflow profile is solved by analyzing the formation of thermal labels (Valiullin et al., 2001, Valiullin et al., 2002), the second is a "small radial-azimuth thermal anemometer - small thermal anemometer", where an induction heater is used to heat the element of the thermal anemometer. In the second case, the problem of estimating the flow direction and estimating the flow rate is solved. For the first approach, "large thermal anemometer", the results of theoretical and experimental studies of the temperature field distribution in a physical model as close as possible to the design of a real oil well, with induction heating of the column taking into account the column flow of liquid. The influence of forced convection on the readings of temperature sensors with different locations in the well (pressed against the inner wall of the column, along the axis of the device) is studied. The advantages of the azimuthal location of temperature sensors when measuring temperature anomalies of the column motion of a liquid are shown. It is established that with the help of an azimuthally distributed temperature probe, it is possible to determine the column flow "from above" when measuring above and below the heating point of the inductor. The optimal time intervals for measuring the temperature at which the allocation of channels for the column movement of the liquid is most effective are determined. For the second approach, "small thermal anemometer", the design features of a borehole thermoconductive indicator of the inflow of indirect heating, which is heated using an induction heater, are considered. Using an induction heater, a uniform heating of the housing of the borehole thermoconductive inflow indicator is achieved. Due to the developed design, the sensor is able to detect the presence of a liquid flow directed perpendicular to the body, and determine the direction of this flow. The "large thermal anemometer" technology has been tested, which has shown its effectiveness and prospects for using it to determine backwater flows (column circulation), but there are still questions related to assessing the effect of thermal convection on the recorded temperature and the possibility of diagnosing the column circulation channel (Valiullin et al., 2017). The article (Valiullin et al., 2008) describes the developed equipment of the "active thermometry" method for conducting geophysical studies of wells, while the classical location of temperature sensors along the axis of the device is used in the borehole probe, which does not make it possible to determine the channels of the circulation channels. The sensors located in this way are more susceptible to the influence of thermal convection, while the change in t
本文考虑了两种基于感应加热器使用的方法:第一种是“大型热风速计”，通过感应作用加热机壳，通过分析热标签的形成来解决确定柱流、确定流速和流入剖面的问题(Valiullin et al.， 2001, Valiullin et al.， 2002);第二种是“小型径向-方位热风速计-小型热风速计”，利用感应加热器加热热风速计的元件。在第二种情况下，解决了估计流向和估计流量的问题。对于第一种方法“大热风速计”，理论和实验研究的结果在一个物理模型中设计的温度场分布尽可能接近于真实油井，同时考虑了塔柱感应加热时液体的塔柱流动情况。研究了强制对流对井内不同位置温度传感器读数的影响(沿装置轴线压在塔身内壁上)。说明了温度传感器在测量液体柱运动温度异常时的方位定位优势。利用方位分布的温度探头，在电感器发热点的上方和下方测量时，可以“从上方”确定柱流。确定了测量温度的最佳时间间隔，在此时间间隔内，液体柱运动通道的分配是最有效的。对于第二种方法“小型热风速计”，考虑了间接加热流入的井眼热传导指示器的设计特点，该指示器使用感应加热器加热。利用感应加热器，实现了对井眼热传导流入指示器外壳的均匀加热。由于开发的设计，传感器能够检测到垂直于身体的液体流动的存在，并确定该流动的方向。“大型热风速计”技术已经过测试，显示了其用于确定回水流量(柱环流)的有效性和前景，但在评估热对流对记录温度的影响以及诊断柱环流通道的可能性方面仍存在问题(Valiullin et al.， 2017)。文章(Valiullin et al.， 2008)描述了用于进行井的地球物理研究的“主动测温”方法的开发设备，而在钻孔探头中使用的是沿着设备轴线的温度传感器的传统位置，这使得无法确定循环通道的通道。这种位置的传感器更容易受到热对流的影响，而流体的速度和成分的变化可以估计为环流通道的存在。为此，开展了减少对流影响的工作，开发了温度探头的设计，使热对流的影响降到最低，提高了循环通道的分配效率。热风速计，又称热风速传感器(井眼热传导流入指示器)，已广泛应用于野外地球物理(Zhuvagin et al.， 1973)。传统的热风速计传感器，有其所有的优点，但也不是没有缺点，其中之一是不能明确地确定垂直于其身体的流体流动的存在和方向。该问题的解决方案将允许，连同已知的解决问题，增加温度计传感器的信息内容，即，在检测柱的泄漏，评估低借的操作间隔，流动方向方面。本工作在采用间接感应加热器的基础上解决了这一问题。
{"title":"The Use of Induction Heating in Assessing the Technical Condition and Operating Intervals in Producing Wells","authors":"R. Sharafutdinov, R. Valiullin, D. Kosmylin, Ayrat Ramazanov, Vladimir Fedotov, V. V. Bajenov, A. I. Imaev","doi":"10.2118/206625-ms","DOIUrl":"https://doi.org/10.2118/206625-ms","url":null,"abstract":"\u0000 The paper considers two approaches based on the use of an induction heater: the first is a \"large thermal anemometer\", in which the casing is heated by induction action and the problem of determining column flows, determining the flow rate and the inflow profile is solved by analyzing the formation of thermal labels (Valiullin et al., 2001, Valiullin et al., 2002), the second is a \"small radial-azimuth thermal anemometer - small thermal anemometer\", where an induction heater is used to heat the element of the thermal anemometer. In the second case, the problem of estimating the flow direction and estimating the flow rate is solved.\u0000 For the first approach, \"large thermal anemometer\", the results of theoretical and experimental studies of the temperature field distribution in a physical model as close as possible to the design of a real oil well, with induction heating of the column taking into account the column flow of liquid. The influence of forced convection on the readings of temperature sensors with different locations in the well (pressed against the inner wall of the column, along the axis of the device) is studied. The advantages of the azimuthal location of temperature sensors when measuring temperature anomalies of the column motion of a liquid are shown. It is established that with the help of an azimuthally distributed temperature probe, it is possible to determine the column flow \"from above\" when measuring above and below the heating point of the inductor. The optimal time intervals for measuring the temperature at which the allocation of channels for the column movement of the liquid is most effective are determined.\u0000 For the second approach, \"small thermal anemometer\", the design features of a borehole thermoconductive indicator of the inflow of indirect heating, which is heated using an induction heater, are considered. Using an induction heater, a uniform heating of the housing of the borehole thermoconductive inflow indicator is achieved. Due to the developed design, the sensor is able to detect the presence of a liquid flow directed perpendicular to the body, and determine the direction of this flow.\u0000 The \"large thermal anemometer\" technology has been tested, which has shown its effectiveness and prospects for using it to determine backwater flows (column circulation), but there are still questions related to assessing the effect of thermal convection on the recorded temperature and the possibility of diagnosing the column circulation channel (Valiullin et al., 2017). The article (Valiullin et al., 2008) describes the developed equipment of the \"active thermometry\" method for conducting geophysical studies of wells, while the classical location of temperature sensors along the axis of the device is used in the borehole probe, which does not make it possible to determine the channels of the circulation channels. The sensors located in this way are more susceptible to the influence of thermal convection, while the change in t","PeriodicalId":10970,"journal":{"name":"Day 1 Tue, October 12, 2021","volume":"394 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73489162","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}
O. N. Morozov, Maksim Andriyanov, Mikhail Sergeevich Ivlev, A. V. Koloda, A. Gabdullin, Vadim Akramovich Agadullin
This article describes the implementation process for use of robotic equipment to perform production logging in extended horizontal production wells equipped with a Y-Tool bypass system. The article describes in detail the process of searching for technological solutions from bench tests to the introduction of technology in the field. The described technology allowed the Company to find a solution to work with the Y-Tool bypass system in the production wells of the Prirazlomnoye field.
{"title":"Applying of Robotic Equipment to Perform Production Logging Operations in Extended Horizontal Exploration Wells Equipped with the Y-Tool System","authors":"O. N. Morozov, Maksim Andriyanov, Mikhail Sergeevich Ivlev, A. V. Koloda, A. Gabdullin, Vadim Akramovich Agadullin","doi":"10.2118/206626-ms","DOIUrl":"https://doi.org/10.2118/206626-ms","url":null,"abstract":"\u0000 This article describes the implementation process for use of robotic equipment to perform production logging in extended horizontal production wells equipped with a Y-Tool bypass system. The article describes in detail the process of searching for technological solutions from bench tests to the introduction of technology in the field.\u0000 The described technology allowed the Company to find a solution to work with the Y-Tool bypass system in the production wells of the Prirazlomnoye field.","PeriodicalId":10970,"journal":{"name":"Day 1 Tue, October 12, 2021","volume":"30 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87239286","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. Yarullin, R. Valiullin, A. Yarullin, Dmitry Nikolaevich Mihailov, Valery Vasilyevich Shako, M. Bikkulov
This paper is devoted to the problem of informative value and interpretation reliability of wide frequency range acoustic noise technique in operating horizontal wells considering results of laboratory experiments conducted with wellbore mockups. The set of factors affecting the spectrum of acoustic noise recorded in wellbore were experimentally investigated and the necessity for calibrating of noise logging tools to provide results of acoustic measurements in the unified scale is also discussed.
{"title":"Informative Value and Interpretation Reliability of Wide Frequency Range Acoustic Noise Technique in Operating Horizontal Wells","authors":"R. Yarullin, R. Valiullin, A. Yarullin, Dmitry Nikolaevich Mihailov, Valery Vasilyevich Shako, M. Bikkulov","doi":"10.2118/206619-ms","DOIUrl":"https://doi.org/10.2118/206619-ms","url":null,"abstract":"\u0000 This paper is devoted to the problem of informative value and interpretation reliability of wide frequency range acoustic noise technique in operating horizontal wells considering results of laboratory experiments conducted with wellbore mockups. The set of factors affecting the spectrum of acoustic noise recorded in wellbore were experimentally investigated and the necessity for calibrating of noise logging tools to provide results of acoustic measurements in the unified scale is also discussed.","PeriodicalId":10970,"journal":{"name":"Day 1 Tue, October 12, 2021","volume":"44 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81719188","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}
Abdullah Ashkanani, Hessa Rashed, Dalal Al-Ohali, Bedour Al-Ansari, Balqees Al-Ibrahim, Rakan Al-Bader, B. Sadiq, Mohammad Hassan, Haya Abalkhail
The Ministry of Oil (MOO) is going with new task to realize the New Kuwait Vision, and so, MOO is on track to shift to a complete digital work environment. Preliminary steps toward the transformation arose with a high concern of connecting with one of the main stakeholders, the Kuwait Oil Company. All in optimism to modernize the data digitally between the Kuwait Oil Company and the Ministry of Oil when it comes to the Technical papers proposal. Based on such, many more motives appeared to modify the work process from manual to digital. Therefore, crucial plans were established based on calculated plans set by managerial personnel to group delegated tasks. As an outcome, the staff with recognizable capabilities dispersed these tasks and executed most using current applications. In the ancient systems, papers that used to take around 21 working days to be reviewed from start to finish, now in a days with the digital system, take around 3 days only, saving a lot of time and resources for each technical paper that is submitted through this new and improved system. Of course, guaranteeing a paperless route brought about many challenges and worries. The most important of them being the reassurance of security measures to protect personnel and the data sharing process. Additionally, the reception of senior workforces to change habits and relearn new procedures of producing daily tasks, as well as, increasing the capability through training courses and supervision. Furthermore, tackling errors exposed within the system through trial and error to boost the experience and optimize workflow.
{"title":"Digitization of the Upstream Data Shared from the Private Sector to the Government Sector","authors":"Abdullah Ashkanani, Hessa Rashed, Dalal Al-Ohali, Bedour Al-Ansari, Balqees Al-Ibrahim, Rakan Al-Bader, B. Sadiq, Mohammad Hassan, Haya Abalkhail","doi":"10.2118/206603-ms","DOIUrl":"https://doi.org/10.2118/206603-ms","url":null,"abstract":"\u0000 The Ministry of Oil (MOO) is going with new task to realize the New Kuwait Vision, and so, MOO is on track to shift to a complete digital work environment. Preliminary steps toward the transformation arose with a high concern of connecting with one of the main stakeholders, the Kuwait Oil Company. All in optimism to modernize the data digitally between the Kuwait Oil Company and the Ministry of Oil when it comes to the Technical papers proposal.\u0000 Based on such, many more motives appeared to modify the work process from manual to digital. Therefore, crucial plans were established based on calculated plans set by managerial personnel to group delegated tasks. As an outcome, the staff with recognizable capabilities dispersed these tasks and executed most using current applications.\u0000 In the ancient systems, papers that used to take around 21 working days to be reviewed from start to finish, now in a days with the digital system, take around 3 days only, saving a lot of time and resources for each technical paper that is submitted through this new and improved system.\u0000 Of course, guaranteeing a paperless route brought about many challenges and worries. The most important of them being the reassurance of security measures to protect personnel and the data sharing process. Additionally, the reception of senior workforces to change habits and relearn new procedures of producing daily tasks, as well as, increasing the capability through training courses and supervision. Furthermore, tackling errors exposed within the system through trial and error to boost the experience and optimize workflow.","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":"89242264","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}
Multidepth electromagnetic logging tool is considered as traditional measurements of formation resistivity estimation while drilling. When considering data in wells with high angles trajectory, more than 70 degrees, the resistivity measurements could be affected by several factors associated with geological conditions and logging tool specifications. As the result, during water saturation estimation formation properties could be distorted, which will lead to significant effect of reservoir properties assessment and the design of the horizontal well completion. Within the framework of this paper, various methods of influence on the resistivity readings will be considered, especially with cross boundary effects and reservoir formations with anisotropy. At the same time, propagation resistivity logging technologies while drilling with interpretation and boundary propagation technologies will be observed, which has tilted azimuthal oriented receivers for geosteering service of horizontal wells and additionally helps with take into account of boundary enflurane on standard resistivity logging.
{"title":"Propogation LWD Tool Analysing for Better Saturation Estimation in High Angle Horizontal Well Conditions","authors":"A. Mingazov, A. Zhidkov, M. Nukhaev","doi":"10.2118/206624-ms","DOIUrl":"https://doi.org/10.2118/206624-ms","url":null,"abstract":"\u0000 Multidepth electromagnetic logging tool is considered as traditional measurements of formation resistivity estimation while drilling. When considering data in wells with high angles trajectory, more than 70 degrees, the resistivity measurements could be affected by several factors associated with geological conditions and logging tool specifications. As the result, during water saturation estimation formation properties could be distorted, which will lead to significant effect of reservoir properties assessment and the design of the horizontal well completion.\u0000 Within the framework of this paper, various methods of influence on the resistivity readings will be considered, especially with cross boundary effects and reservoir formations with anisotropy. At the same time, propagation resistivity logging technologies while drilling with interpretation and boundary propagation technologies will be observed, which has tilted azimuthal oriented receivers for geosteering service of horizontal wells and additionally helps with take into account of boundary enflurane on standard resistivity logging.","PeriodicalId":10970,"journal":{"name":"Day 1 Tue, October 12, 2021","volume":"117 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90257374","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}
Ilnar Nailevich Sabirov, Anton Vladimirovich Kristya
Geosteering is usually responsible for addressing geological uncertainties, such as the uncertainty in the position of the horizon structure or the structural dip angle. During drilling, the directional survey measurements are taken as true, whilst the uncertainties related to the instruments are not considered. Measurement errors cannot be completely excluded, but they can be reduced to a minimum (reducing the "ellipse of uncertainty" of measurements) by considering the variability of the Earth's magnetic field and the influence of the external factors on the tool (by employing quality control and correction of directional measurements), as a result, reducing the risks of crossing the fluid contacts by the wellbore. This work is devoted to the methods of detecting and minimizing the inclinometer measurement error while drilling, as well as the application of the results for geological support of drilling. The article describes the principle of the methodology for correcting the inclinometer measurements while drilling and indicates the cases in which the correction method is applicable. The paper considers the prerequisites for using the measurement quality control method and tools to reduce the measurement error in these cases. The possibility of using the method of geomagnetic referencing IFR, as well as methods for correcting measurements of the telemetry system BHA Sag and MSA, to fulfill geological tasks is considered. This paper provides an example of quality control of directional measurements after drilling a well with an extended horizontal section. In the course of the work, the values of measurement errors along the vertical and lateral were established at a large deviation from the wellhead of the considered well. Attention is focused on the analysis of the identified inclinometry errors, their consequences and impact on the geological drilling of the wellbore and considered an example of improving the quality of geological support using the method of correcting directional measurements while drilling.
{"title":"Survey Management During Geosteering","authors":"Ilnar Nailevich Sabirov, Anton Vladimirovich Kristya","doi":"10.2118/206628-ms","DOIUrl":"https://doi.org/10.2118/206628-ms","url":null,"abstract":"\u0000 Geosteering is usually responsible for addressing geological uncertainties, such as the uncertainty in the position of the horizon structure or the structural dip angle. During drilling, the directional survey measurements are taken as true, whilst the uncertainties related to the instruments are not considered. Measurement errors cannot be completely excluded, but they can be reduced to a minimum (reducing the \"ellipse of uncertainty\" of measurements) by considering the variability of the Earth's magnetic field and the influence of the external factors on the tool (by employing quality control and correction of directional measurements), as a result, reducing the risks of crossing the fluid contacts by the wellbore.\u0000 This work is devoted to the methods of detecting and minimizing the inclinometer measurement error while drilling, as well as the application of the results for geological support of drilling. The article describes the principle of the methodology for correcting the inclinometer measurements while drilling and indicates the cases in which the correction method is applicable. The paper considers the prerequisites for using the measurement quality control method and tools to reduce the measurement error in these cases. The possibility of using the method of geomagnetic referencing IFR, as well as methods for correcting measurements of the telemetry system BHA Sag and MSA, to fulfill geological tasks is considered.\u0000 This paper provides an example of quality control of directional measurements after drilling a well with an extended horizontal section. In the course of the work, the values of measurement errors along the vertical and lateral were established at a large deviation from the wellhead of the considered well. Attention is focused on the analysis of the identified inclinometry errors, their consequences and impact on the geological drilling of the wellbore and considered an example of improving the quality of geological support using the method of correcting directional measurements while drilling.","PeriodicalId":10970,"journal":{"name":"Day 1 Tue, October 12, 2021","volume":"46 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90557031","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
S. Shtun, A. Senkov, O. Abramenko, I. Nikishin, E. Efimov, Radik Minakhmetov, I. Platonov, M. Nukhaev, V. Kabanov
The paper presents a novel technology for determining the intervals of gas and water breakthrough in the development of fields on the Russian shelf of the Caspian Sea. The proposed technology is similar to traditional production logging and monitoring of horizontal wells using fiber optic systems. The technology aimed at determining the phase components is based on chromate desorption systems (CDS) with individual selective analytes used. CDS are installed on the lower well completion equipment (sand filters, inflow control devices, multistage hydraulic fracturing equipment and so on) and have a unique combination of pairs of oil-, water- and gas-soluble analytes for each interval. From the CDS, an analyte begins to release when in contact with a target fluid to surface with this fluid. At the wellhead, samples are taken according to a specific program, then laboratory analysis by chromatographic methods and mathematical interpretation of the composition of the inflow are performed. The paper presents an example of work when the intervals of gas outs were determined directly in the field using a micro-chromatograph.
{"title":"Technology for Monitoring Gas and Water Breakthrough Intervals using Chromate Desorption Systems in the Development of Fields in the Caspian Sea","authors":"S. Shtun, A. Senkov, O. Abramenko, I. Nikishin, E. Efimov, Radik Minakhmetov, I. Platonov, M. Nukhaev, V. Kabanov","doi":"10.2118/206623-ms","DOIUrl":"https://doi.org/10.2118/206623-ms","url":null,"abstract":"\u0000 The paper presents a novel technology for determining the intervals of gas and water breakthrough in the development of fields on the Russian shelf of the Caspian Sea. The proposed technology is similar to traditional production logging and monitoring of horizontal wells using fiber optic systems.\u0000 The technology aimed at determining the phase components is based on chromate desorption systems (CDS) with individual selective analytes used. CDS are installed on the lower well completion equipment (sand filters, inflow control devices, multistage hydraulic fracturing equipment and so on) and have a unique combination of pairs of oil-, water- and gas-soluble analytes for each interval. From the CDS, an analyte begins to release when in contact with a target fluid to surface with this fluid. At the wellhead, samples are taken according to a specific program, then laboratory analysis by chromatographic methods and mathematical interpretation of the composition of the inflow are performed. The paper presents an example of work when the intervals of gas outs were determined directly in the field using a micro-chromatograph.","PeriodicalId":10970,"journal":{"name":"Day 1 Tue, October 12, 2021","volume":"328 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78419731","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. Varavva, R. Apasov, D. A. Samolovov, A. V. Elesin, G. T. Apasov, Evgeniya Vladimirovna Voyevoda, Dmitry Anatolevich Reshetnikov, Maxim Arkadievich Senachin
The paper describes the experience of building a full-field integrated model (PK1 reservoir) of the Tazovskoye field, including a model of the reservoir, wells, and a gathering network, taking into account the external transportation system. In order to integrate the features of the field, such as the simultaneous development of a thin oil rim and a gas cap, high growth rates of the gas-oil ratio, oil wells - both ESP-operated and flowing, algorithms and tools have been developed, which are discussed in the paper. The results of the integrated model runs are given, main features of the solutions are highlighted.
{"title":"Creating the Integrated Model for Conceptual Engineering of Reservoir Management and Field Facilities Construction – Experience of Tazovskoe Oil and Gas-Condensate Field.","authors":"A. Varavva, R. Apasov, D. A. Samolovov, A. V. Elesin, G. T. Apasov, Evgeniya Vladimirovna Voyevoda, Dmitry Anatolevich Reshetnikov, Maxim Arkadievich Senachin","doi":"10.2118/206540-ms","DOIUrl":"https://doi.org/10.2118/206540-ms","url":null,"abstract":"\u0000 The paper describes the experience of building a full-field integrated model (PK1 reservoir) of the Tazovskoye field, including a model of the reservoir, wells, and a gathering network, taking into account the external transportation system. In order to integrate the features of the field, such as the simultaneous development of a thin oil rim and a gas cap, high growth rates of the gas-oil ratio, oil wells - both ESP-operated and flowing, algorithms and tools have been developed, which are discussed in the paper. The results of the integrated model runs are given, main features of the solutions are highlighted.","PeriodicalId":10970,"journal":{"name":"Day 1 Tue, October 12, 2021","volume":"160 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82120335","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}
Denis Nikolaevich Platon, Aidar Ramilovich Gatin, M. N. Fomin, N. Korostelev
The main goal of this work is to evaluate and select the best strategy for the development of the field in the first stage of development. To solve this problem, a full-scale integrated model was created that takes into account the physics of the reservoir, wells and surface infrastructure, as well as their mutual influence. The integrated model was calculated for the full development of the asset. The integrated model of the A. Zhagrin field is based on three simulation models, well models and surface infrastructure, which are linked through an integrator program. All constituent parts of the model are configured to accurately reproduce their actual operation. Greenfield is characterized as active drilling, so the planned well count is modeled by replacing wells with "typical" well models, which are selected by taking into account the expected input flow rate, well design, well completion and well trajectory. Fields of the first stage of development are characterized by limitations related to oil transportation and treatment. These constraints are also specified and taken into account in the model The concept of surface infrastructure is formed depending on the potential production capabilities of the reservoir and has considerable variability. The total number of actual and planned wells in the field is more than 1,300, including more than 700 production wells and about 600 injection wells. All wells are ESP lifted. Considering infrastructure capacity constraints and requirements for optimal pipeline utilization, the use of different numbers of drilling rigs directly affecting the utilization of oil treatment and delivery facilities was evaluated. 29 main variations of the field development strategy until 2060 were formed and calculated, based on the integrated model. The main parameters of variation were the capacity of preparation facilities, the degree of oil separation, the scheme of product transportation, gas utilization capabilities, drilling rigs and subsurface equipment. All scenarios in the integrated model took into account constraints - on target bottomhole, wellhead and line pressures, in order to operate real facilities in accident-free mode. In the course of calculations, an optimal scenario was selected, which made it possible to increase oil production in 2021 by optimizing the transportation of produced products to the treatment facilities. This scenario formed the basis of the asset development strategy.
{"title":"Full Integrated Model as a Tool for Strategy Evaluation of the Greenfield","authors":"Denis Nikolaevich Platon, Aidar Ramilovich Gatin, M. N. Fomin, N. Korostelev","doi":"10.2118/206552-ms","DOIUrl":"https://doi.org/10.2118/206552-ms","url":null,"abstract":"\u0000 The main goal of this work is to evaluate and select the best strategy for the development of the field in the first stage of development. To solve this problem, a full-scale integrated model was created that takes into account the physics of the reservoir, wells and surface infrastructure, as well as their mutual influence. The integrated model was calculated for the full development of the asset.\u0000 The integrated model of the A. Zhagrin field is based on three simulation models, well models and surface infrastructure, which are linked through an integrator program. All constituent parts of the model are configured to accurately reproduce their actual operation.\u0000 Greenfield is characterized as active drilling, so the planned well count is modeled by replacing wells with \"typical\" well models, which are selected by taking into account the expected input flow rate, well design, well completion and well trajectory. Fields of the first stage of development are characterized by limitations related to oil transportation and treatment. These constraints are also specified and taken into account in the model\u0000 The concept of surface infrastructure is formed depending on the potential production capabilities of the reservoir and has considerable variability.\u0000 The total number of actual and planned wells in the field is more than 1,300, including more than 700 production wells and about 600 injection wells. All wells are ESP lifted.\u0000 Considering infrastructure capacity constraints and requirements for optimal pipeline utilization, the use of different numbers of drilling rigs directly affecting the utilization of oil treatment and delivery facilities was evaluated.\u0000 29 main variations of the field development strategy until 2060 were formed and calculated, based on the integrated model. The main parameters of variation were the capacity of preparation facilities, the degree of oil separation, the scheme of product transportation, gas utilization capabilities, drilling rigs and subsurface equipment. All scenarios in the integrated model took into account constraints - on target bottomhole, wellhead and line pressures, in order to operate real facilities in accident-free mode.\u0000 In the course of calculations, an optimal scenario was selected, which made it possible to increase oil production in 2021 by optimizing the transportation of produced products to the treatment facilities. This scenario formed the basis of the asset development strategy.","PeriodicalId":10970,"journal":{"name":"Day 1 Tue, October 12, 2021","volume":"35 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87083298","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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