Mahdi Mahmoudi, Morteza Roostaei, Vahidoddin Fattahpour, Colby Sutton, B. Fermaniuk, Da Zhu, Hee-Ju Jung, Jiankuan Li, C. Sun, L. Gong, S. Shuang, Xiaoyong Qiu, Hongbo Zeng, Jingli Luo
Standalone screen has been widely used as sand control solution in oil industries for over a century. Screen plugging and impairments by formation fines, scaling and corrosion cost oil and gas industry significant amount of resources. This study presents a detailed study on the corrosion and plugging of slotted liner, wire wrap screen and mesh screen samples extracted from the field to better understand some of the mechanisms for these poor field performances. Three types of standalone screen were received from operating wells to study the failure mechanism of the screen and provide recommendations for recompletion. A thorough visual inspection of all screens was performed and documented in this paper. From the results of the visual inspection a certain section of each screen was cut for further detailed microscopic study to better understand the scaling and plugging mechanism, as well as microscopic geometry of the plugged and corroded zone. The results highlighted the importance of the corrosion in the base pipe on the observed performances. All the studies pointed toward the flow dependence corrosion behavior, and the role of the water cut on the corrosion rate. The wire wrap screens have been in service for less than a year, yet the extensive corrosion led to creation of several holes in the pipe. The study showed the corrosion initiated from inside the pipe. Similarly, the corrosion of the slotted liner samples showed a strong flow dependent corrosion rate, where the corrosion rate on the slot/formation interface was slightly higher. The mesh screen showed very high plugging percentage by formation fines, where a thick film of clay and fine sand covered the space between the mesh and the base pipe. The results indicated that an inappropriate design of the mesh and pore could cause significant plugging. This paper provides several field examples of the corrosion and plugging of the standalone screens. The results could help engineer to better understand the risk of corrosion and plugging on the standalone screen design. This paper provides some general guidelines for assessing the scaling and corrosion potential at field condition based on the results of the screens studied in the paper.
{"title":"Standalone Sand Control Failure: Review of Slotted Liner, Wire Wrap Screen, and Premium Mesh Screen Failure Mechanism","authors":"Mahdi Mahmoudi, Morteza Roostaei, Vahidoddin Fattahpour, Colby Sutton, B. Fermaniuk, Da Zhu, Hee-Ju Jung, Jiankuan Li, C. Sun, L. Gong, S. Shuang, Xiaoyong Qiu, Hongbo Zeng, Jingli Luo","doi":"10.2118/191553-MS","DOIUrl":"https://doi.org/10.2118/191553-MS","url":null,"abstract":"\u0000 Standalone screen has been widely used as sand control solution in oil industries for over a century. Screen plugging and impairments by formation fines, scaling and corrosion cost oil and gas industry significant amount of resources. This study presents a detailed study on the corrosion and plugging of slotted liner, wire wrap screen and mesh screen samples extracted from the field to better understand some of the mechanisms for these poor field performances.\u0000 Three types of standalone screen were received from operating wells to study the failure mechanism of the screen and provide recommendations for recompletion. A thorough visual inspection of all screens was performed and documented in this paper. From the results of the visual inspection a certain section of each screen was cut for further detailed microscopic study to better understand the scaling and plugging mechanism, as well as microscopic geometry of the plugged and corroded zone.\u0000 The results highlighted the importance of the corrosion in the base pipe on the observed performances. All the studies pointed toward the flow dependence corrosion behavior, and the role of the water cut on the corrosion rate. The wire wrap screens have been in service for less than a year, yet the extensive corrosion led to creation of several holes in the pipe. The study showed the corrosion initiated from inside the pipe. Similarly, the corrosion of the slotted liner samples showed a strong flow dependent corrosion rate, where the corrosion rate on the slot/formation interface was slightly higher. The mesh screen showed very high plugging percentage by formation fines, where a thick film of clay and fine sand covered the space between the mesh and the base pipe. The results indicated that an inappropriate design of the mesh and pore could cause significant plugging.\u0000 This paper provides several field examples of the corrosion and plugging of the standalone screens. The results could help engineer to better understand the risk of corrosion and plugging on the standalone screen design. This paper provides some general guidelines for assessing the scaling and corrosion potential at field condition based on the results of the screens studied in the paper.","PeriodicalId":11015,"journal":{"name":"Day 1 Mon, September 24, 2018","volume":"72 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86284338","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}
Wei‐Ting Dai, Brian Noel, C. Alvord, Johnson Njoku, Joseph A. Hopper, Lee M. Smith
Casing wear caused by rotating drill strings can lead to reduced well life, failed or burst casing strings, and expensive non-productive time (NPT) for remedial actions. In Alaska's Alpine Development field, where logistics are challenging, regulations are strict, and the operational window is small, drilling increasingly long laterals has vastly increased the cost and risk of casing wear, necessitating effective mitigation. After detailed analyses of Alpine field wells, one operator successfully implemented a casing wear mitigation plan combining new tools, modeling techniques and analyses. The plan required strategic placement of Non-Rotating Protectors (NRPs) based on predicted casing wear, analyzed side forces, and lateral length. Additionally, the operations group wanted to simultaneously improve computer modeling for both casing wear and torque and drag (T&D) analysis. One major challenge was predicting appropriate wear factors for casing wear modeling. Operational challenges included how to deploy the plan in managed pressure drilling (MPD) operations, where preventing premature wear on rotating control device (RCD) sealing elements had to be considered. Implementing this casing wear mitigation plan allowed the operator to successfully drill extended reach multilateral wells to planned total depth while keeping wear below maximum allowable thresholds. The paper describes the challenges and approach to predict casing wear, as well as successful mitigation strategies and lessons learned from an extensive offset database. Included are comparisons to field results from casing logs, and several wells that deployed the casing wear mitigation plan, versus an offset well that was drilled without a plan. The paper describes new techniques for predicting and modeling casing wear which, in combination with utilization of specific tools, results in a readily-applicable approach to wear mitigation in extended-reach drilling (ERD).
{"title":"A Practical Approach to Casing Wear Prediction, Modeling and Mitigation on Challenging ERD Wells","authors":"Wei‐Ting Dai, Brian Noel, C. Alvord, Johnson Njoku, Joseph A. Hopper, Lee M. Smith","doi":"10.2118/191495-MS","DOIUrl":"https://doi.org/10.2118/191495-MS","url":null,"abstract":"\u0000 Casing wear caused by rotating drill strings can lead to reduced well life, failed or burst casing strings, and expensive non-productive time (NPT) for remedial actions. In Alaska's Alpine Development field, where logistics are challenging, regulations are strict, and the operational window is small, drilling increasingly long laterals has vastly increased the cost and risk of casing wear, necessitating effective mitigation.\u0000 After detailed analyses of Alpine field wells, one operator successfully implemented a casing wear mitigation plan combining new tools, modeling techniques and analyses. The plan required strategic placement of Non-Rotating Protectors (NRPs) based on predicted casing wear, analyzed side forces, and lateral length. Additionally, the operations group wanted to simultaneously improve computer modeling for both casing wear and torque and drag (T&D) analysis.\u0000 One major challenge was predicting appropriate wear factors for casing wear modeling. Operational challenges included how to deploy the plan in managed pressure drilling (MPD) operations, where preventing premature wear on rotating control device (RCD) sealing elements had to be considered.\u0000 Implementing this casing wear mitigation plan allowed the operator to successfully drill extended reach multilateral wells to planned total depth while keeping wear below maximum allowable thresholds. The paper describes the challenges and approach to predict casing wear, as well as successful mitigation strategies and lessons learned from an extensive offset database. Included are comparisons to field results from casing logs, and several wells that deployed the casing wear mitigation plan, versus an offset well that was drilled without a plan.\u0000 The paper describes new techniques for predicting and modeling casing wear which, in combination with utilization of specific tools, results in a readily-applicable approach to wear mitigation in extended-reach drilling (ERD).","PeriodicalId":11015,"journal":{"name":"Day 1 Mon, September 24, 2018","volume":"37 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89962691","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}
Zac Arackakudiyil Suresh, Ajit Kumar, L. Rondon, Darshan Pingle, Khaled Al-Hindi, M. Boushahri
Multilateral intelligent wells have been proven effective by both extending reservoir contact and providing proactive reservoir management. This paper highlights the lessons learned and critical well construction and completion steps that improve the efficiency of intelligent multilateral well drilling and completions operations. The case study outlines the successful completion of the third multilateral intelligent well in the Minagish field of West Kuwait. The intelligent level 4 multilateral well was designed and drilled successfully. The sidetrack was performed using a specialized latch coupling that allowed for multilateral window cutting, orienting, and re-entry. The latch coupling was run in hole with the main bore casing, and a key orienting tool was used to confirm its orientation. Once the main bore was complete, a window was cut using a dedicated milling machine. Thereafter, a drilling whipstock was run with a window mill and watermelon mill to allow access to the lateral. This was followed by drilling the lateral section and running and cementing the liner. After the lateral section was drilled to the planned depth and cleaned out, the whipstock was retrieved. The intelligent completion installation consisted of a lubricator valve, two downhole permanent gauges, and two variable choke interval control valves. The presence of surface-controlled, variable choke valves to control inflow from both the main bore and the lateral provides the capability to effectively manage the reservoir and production over the life of the well. This, in turn, prolongs the field life, thus improving overall economic performance and field economics. The case study well is the third multilateral intelligent well installed in Kuwait, and many recommended practices were implemented that allowed for improved efficiency and safety of the operation. Maintaining a clean well was emphasized as a top priority throughout the well construction process. The cement curing time was increased and the completion string was reviewed and redesigned. This paper discusses the lessons learned and improvements made during installation of the third multilateral intelligent well. The steps performed during this operation have become the recommended practices for all upcoming intelligent multilateral well operations in Kuwait.
{"title":"Challenges and Lessons Learned During Completion of Intelligent Multilateral Wells in Minagish Field, West Kuwait","authors":"Zac Arackakudiyil Suresh, Ajit Kumar, L. Rondon, Darshan Pingle, Khaled Al-Hindi, M. Boushahri","doi":"10.2118/191742-MS","DOIUrl":"https://doi.org/10.2118/191742-MS","url":null,"abstract":"Multilateral intelligent wells have been proven effective by both extending reservoir contact and providing proactive reservoir management. This paper highlights the lessons learned and critical well construction and completion steps that improve the efficiency of intelligent multilateral well drilling and completions operations. The case study outlines the successful completion of the third multilateral intelligent well in the Minagish field of West Kuwait. The intelligent level 4 multilateral well was designed and drilled successfully. The sidetrack was performed using a specialized latch coupling that allowed for multilateral window cutting, orienting, and re-entry. The latch coupling was run in hole with the main bore casing, and a key orienting tool was used to confirm its orientation. Once the main bore was complete, a window was cut using a dedicated milling machine. Thereafter, a drilling whipstock was run with a window mill and watermelon mill to allow access to the lateral. This was followed by drilling the lateral section and running and cementing the liner. After the lateral section was drilled to the planned depth and cleaned out, the whipstock was retrieved. The intelligent completion installation consisted of a lubricator valve, two downhole permanent gauges, and two variable choke interval control valves. The presence of surface-controlled, variable choke valves to control inflow from both the main bore and the lateral provides the capability to effectively manage the reservoir and production over the life of the well. This, in turn, prolongs the field life, thus improving overall economic performance and field economics. The case study well is the third multilateral intelligent well installed in Kuwait, and many recommended practices were implemented that allowed for improved efficiency and safety of the operation. Maintaining a clean well was emphasized as a top priority throughout the well construction process. The cement curing time was increased and the completion string was reviewed and redesigned. This paper discusses the lessons learned and improvements made during installation of the third multilateral intelligent well. The steps performed during this operation have become the recommended practices for all upcoming intelligent multilateral well operations in Kuwait.","PeriodicalId":11015,"journal":{"name":"Day 1 Mon, September 24, 2018","volume":"34 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73610799","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}
Hewei Tang, Z. Chai, Youwei He, Boyue Xu, A. Hasan, J. Killough
Liquid loading is an inevitable production issue for mature gas fields. A varied group of phenomena after the onset of liquid loading has been observed in field, including the natural cyclical production of liquid loaded wells. Most previous modeling studies focused on predicting the onset of liquid loading. The production behaviors after the onset of liquid loading is equally important and requires strict modeling techniques to simulate dynamic interactions between wellbores and reservoirs. In this paper, we apply a newly developed fully implicitly coupled well-reservoir simulator to systematically investigate the well behavior after the onset of liquid loading. The model honors the mass and momentum balances in both reservoir and wellbore systems, and thus allows us to analyze both wellbore and reservoir dynamics after the onset of liquid loading. The simulation results indicate that there exist a gas-water coproduction period and a zero liquid production period after the onset of liquid loading. For reservoir permeability as low as 0.1md, the liquid-loaded horizontal well might experience natural cyclical production after the onset of liquid loading, which coincides with field observations. Both uniform stimulation and multi-stage hydraulic fractures help mitigate the production phenomenon. The near-wellbore reservoir pressure build up and wellbore fluid reinjection are also evaluated. This work demonstrates the successful application of the coupled wellbore reservoir model in predicting the rich production phenomena of stimulated horizontal wells after the onset of liquid loading.
{"title":"What Happens after the Onset of Liquid Loading? — An Insight from Coupled Well-Reservoir Simulation","authors":"Hewei Tang, Z. Chai, Youwei He, Boyue Xu, A. Hasan, J. Killough","doi":"10.2118/191629-MS","DOIUrl":"https://doi.org/10.2118/191629-MS","url":null,"abstract":"\u0000 Liquid loading is an inevitable production issue for mature gas fields. A varied group of phenomena after the onset of liquid loading has been observed in field, including the natural cyclical production of liquid loaded wells. Most previous modeling studies focused on predicting the onset of liquid loading. The production behaviors after the onset of liquid loading is equally important and requires strict modeling techniques to simulate dynamic interactions between wellbores and reservoirs.\u0000 In this paper, we apply a newly developed fully implicitly coupled well-reservoir simulator to systematically investigate the well behavior after the onset of liquid loading. The model honors the mass and momentum balances in both reservoir and wellbore systems, and thus allows us to analyze both wellbore and reservoir dynamics after the onset of liquid loading. The simulation results indicate that there exist a gas-water coproduction period and a zero liquid production period after the onset of liquid loading. For reservoir permeability as low as 0.1md, the liquid-loaded horizontal well might experience natural cyclical production after the onset of liquid loading, which coincides with field observations. Both uniform stimulation and multi-stage hydraulic fractures help mitigate the production phenomenon. The near-wellbore reservoir pressure build up and wellbore fluid reinjection are also evaluated. This work demonstrates the successful application of the coupled wellbore reservoir model in predicting the rich production phenomena of stimulated horizontal wells after the onset of liquid loading.","PeriodicalId":11015,"journal":{"name":"Day 1 Mon, September 24, 2018","volume":"9 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88840829","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}
I. M. Ismail, N. Sidik, Faez Syarani Wahi, Giok Lin Tan, Focht Tom, Frazer Hillis
Despite the improved productivity and uplift in reserve recovery associated with horizontal wells, reservoir heterogeneity can cause uneven production, and early water and gas breakthrough from portions of the wellbore. Inflow control devices (ICD) create additional pressure drop to balance the production flux, but cannot restrict unwanted effluents once they break through. The Autonomous Inflow Control Device (AICD) actively delivers a variable flow restriction in response to the properties (viscosity) of the fluid flowing through it. Water or gas flowing through the device is restricted more than oil. When used in a horizontal well, segmented into multiple compartments, this design prevents excessive production of unwanted effluents after breakthrough occurs in one or more compartments. In the 2016 infill development campaign, production was improved by AICDs to ensure contribution from all reservoir sections, and limit gas and water production by postponing breakthrough and restricting unwanted effluent production after breakthrough. A nine well program was selected to demonstrate the effectiveness of AICD completions in the East Belumut and West Belumut assets, a field development offshore Malaysia. The wells are drilled with horizontal lengths typically 1.5km within the original 6-8m thin oil column for West Belumut and 10-14m thin oil column for East Belumut. The program comprised of AICD flow loop testing, performance modelling, candidate selection, completion design and comparing production results with neighbouring ICD wells in the fields. The implementation of an AICD completion was a success and full fields implementation took place in 2017. First installed in March 2016, the AICD completion was adopted as part of the standard lower completion solution at East Belumut. To date additional wells have been completed with AICD completions in East and West Belumut fields, demonstrating significant increase in cumulative oil production, reduction in GOR of the AICD wells by 50%, and achieving 50% more oil production compared to offset ICD wells. This paper describes a full field implementation for the application of AICDs in a super thin layer, oil reservoir offshore Malaysia. Nine new horizontal wells in two different fields were completed with AICDs to reduce the amount of water and gas production from these wells and to enhance the reserve recovery from the asset. The paper describes the workflow for establishing the suitability of candidates for the technology, the completion design process, and the enhanced production results of the program after 2 years production.
尽管水平井提高了产能，提高了采收率，但储层的非均质性会导致产量不均匀，并且会导致部分井眼早期出现水和气突破。流入控制装置(ICD)产生额外的压降来平衡生产流量，但一旦不需要的流出物突破，就不能限制它们。自动流入控制装置(AICD)根据流过它的流体的性质(粘度)主动提供可变流量限制。通过该装置的水或气体比石油更受限制。当在水平井中使用时，分割成多个隔室，这种设计可以防止在一个或多个隔室发生突破后过量产生不需要的废水。在2016年的充填开发活动中，aicd提高了产量，以确保所有储层段的贡献，并通过推迟突破和限制突破后的有害废水产生来限制气和水的产量。在马来西亚海上的一个油田开发项目East Belumut和West Belumut，选择了一个9口井的项目来验证AICD完井的有效性。这些井的水平长度通常为1.5km, West Belumut的原始油柱为6-8m薄，East Belumut的原始油柱为10-14m薄。该项目包括AICD流动循环测试、性能建模、候选井选择、完井设计，并将生产结果与油田邻近的ICD井进行比较。AICD完井作业取得了成功，并于2017年在全油田实施。AICD完井系统于2016年3月首次安装，作为East Belumut地区标准下部完井解决方案的一部分。到目前为止，在Belumut东部和西部油田已经完成了额外的AICD完井，表明累积产油量显著增加，AICD井的GOR降低了50%，与ICD井相比，产量增加了50%。本文介绍了在马来西亚海上超薄层油藏中应用aicd的现场实施情况。采用aicd完成了两个不同油田的9口新水平井，以减少这些井的水和气产量，并提高该资产的储量采收率。本文描述了确定候选技术适用性的工作流程、完井设计过程以及该方案在2年后的生产效果。
{"title":"Increased Oil Production in Super Thin Oil Rim Using the Application of Autonomous Inflow Control Devices","authors":"I. M. Ismail, N. Sidik, Faez Syarani Wahi, Giok Lin Tan, Focht Tom, Frazer Hillis","doi":"10.2118/191590-MS","DOIUrl":"https://doi.org/10.2118/191590-MS","url":null,"abstract":"\u0000 Despite the improved productivity and uplift in reserve recovery associated with horizontal wells, reservoir heterogeneity can cause uneven production, and early water and gas breakthrough from portions of the wellbore. Inflow control devices (ICD) create additional pressure drop to balance the production flux, but cannot restrict unwanted effluents once they break through.\u0000 The Autonomous Inflow Control Device (AICD) actively delivers a variable flow restriction in response to the properties (viscosity) of the fluid flowing through it. Water or gas flowing through the device is restricted more than oil. When used in a horizontal well, segmented into multiple compartments, this design prevents excessive production of unwanted effluents after breakthrough occurs in one or more compartments.\u0000 In the 2016 infill development campaign, production was improved by AICDs to ensure contribution from all reservoir sections, and limit gas and water production by postponing breakthrough and restricting unwanted effluent production after breakthrough.\u0000 A nine well program was selected to demonstrate the effectiveness of AICD completions in the East Belumut and West Belumut assets, a field development offshore Malaysia. The wells are drilled with horizontal lengths typically 1.5km within the original 6-8m thin oil column for West Belumut and 10-14m thin oil column for East Belumut. The program comprised of AICD flow loop testing, performance modelling, candidate selection, completion design and comparing production results with neighbouring ICD wells in the fields.\u0000 The implementation of an AICD completion was a success and full fields implementation took place in 2017. First installed in March 2016, the AICD completion was adopted as part of the standard lower completion solution at East Belumut. To date additional wells have been completed with AICD completions in East and West Belumut fields, demonstrating significant increase in cumulative oil production, reduction in GOR of the AICD wells by 50%, and achieving 50% more oil production compared to offset ICD wells.\u0000 This paper describes a full field implementation for the application of AICDs in a super thin layer, oil reservoir offshore Malaysia. Nine new horizontal wells in two different fields were completed with AICDs to reduce the amount of water and gas production from these wells and to enhance the reserve recovery from the asset. The paper describes the workflow for establishing the suitability of candidates for the technology, the completion design process, and the enhanced production results of the program after 2 years production.","PeriodicalId":11015,"journal":{"name":"Day 1 Mon, September 24, 2018","volume":"79 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89921753","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. Murugesan, D. K. Agrawal, Radhika Suresh, V. Khabashesku, Qusai A. Darugar
Luminescent upconversion nanoparticles are used as alternate fluorescence tracers to overcome the interference of organic molecules in the analysis of flowback waters. Upconversion nanoparticles use low-energy excitation at approximately 980 nm with high-energy emissions in the region of 200 to 950 nm. Emission properties of the nanoparticles are tuned by selective doping, and their dispersiblity in water and oil are altered through appropriate functionalization. The flow experiments used stable crude oil emulsions in API brine with the mixture of two different emission upconversion tracer nanoparticles. Data from these experiments suggest that the nanoparticle tracers can flow through the porous media and distinguish between each other, even in the presence of organics in an emulsion. This capability can open new avenues in in-situ reservoir communication and understanding.
{"title":"Upconversion Nanoparticles as Tracers for Production and Well Monitoring","authors":"S. Murugesan, D. K. Agrawal, Radhika Suresh, V. Khabashesku, Qusai A. Darugar","doi":"10.2118/191659-ms","DOIUrl":"https://doi.org/10.2118/191659-ms","url":null,"abstract":"\u0000 Luminescent upconversion nanoparticles are used as alternate fluorescence tracers to overcome the interference of organic molecules in the analysis of flowback waters. Upconversion nanoparticles use low-energy excitation at approximately 980 nm with high-energy emissions in the region of 200 to 950 nm. Emission properties of the nanoparticles are tuned by selective doping, and their dispersiblity in water and oil are altered through appropriate functionalization. The flow experiments used stable crude oil emulsions in API brine with the mixture of two different emission upconversion tracer nanoparticles. Data from these experiments suggest that the nanoparticle tracers can flow through the porous media and distinguish between each other, even in the presence of organics in an emulsion. This capability can open new avenues in in-situ reservoir communication and understanding.","PeriodicalId":11015,"journal":{"name":"Day 1 Mon, September 24, 2018","volume":"222 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85916003","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. Ogunbanwo, Kuy Hun Koh Yoo, M. Gerritsen, A. Kovscek
This paper presents a new workflow for the simulation of in-situ combustion (ISC) dynamics. In the proposed method, data from kinetic cell experiments, depicting the combustion chemistry, are tabulated and graphed based on the isoconversional principle. The tables hold the reaction rates used to predict the production and consumption of chemical species during in-situ combustion. This new method of representing kinetics without the Arrhenius method is applied on one synthetic and two real kinetic cell experiments. In each case, the new method reasonably captures the reaction pathways taken by the reacting species as the combustive process occurs. A data-density sensitivity study on the tabulated rates for the real case shows that only four experiments are required to capture adequately the kinetics of the combustion process. The results are, however, found to be sensitive to the size of the time step taken. The method predicts critical changes in the reaction rates as the experiment is exposed to different temperature conditions, thereby capturing the speed of the combustion front, temperature profile, and fluid compositions of a simulated combustion tube experiment. The direct use of the data ensures flexibility of the reaction rates with time and temperature. In addition, the non-Arrhenius kinetics technique eliminates the need for a descriptive reaction scheme that is typically computationally demanding, and instead focuses on the overall changes in the carbon oxides, oil, water and heat occurring at any time. Significantly, less tuning of parameters is required to match laboratory experiments because laboratory observations are easier to enforce.
{"title":"Data-Driven Prediction of In-Situ Combustion Dynamics","authors":"O. Ogunbanwo, Kuy Hun Koh Yoo, M. Gerritsen, A. Kovscek","doi":"10.2118/191457-MS","DOIUrl":"https://doi.org/10.2118/191457-MS","url":null,"abstract":"\u0000 This paper presents a new workflow for the simulation of in-situ combustion (ISC) dynamics. In the proposed method, data from kinetic cell experiments, depicting the combustion chemistry, are tabulated and graphed based on the isoconversional principle. The tables hold the reaction rates used to predict the production and consumption of chemical species during in-situ combustion.\u0000 This new method of representing kinetics without the Arrhenius method is applied on one synthetic and two real kinetic cell experiments. In each case, the new method reasonably captures the reaction pathways taken by the reacting species as the combustive process occurs. A data-density sensitivity study on the tabulated rates for the real case shows that only four experiments are required to capture adequately the kinetics of the combustion process. The results are, however, found to be sensitive to the size of the time step taken. The method predicts critical changes in the reaction rates as the experiment is exposed to different temperature conditions, thereby capturing the speed of the combustion front, temperature profile, and fluid compositions of a simulated combustion tube experiment.\u0000 The direct use of the data ensures flexibility of the reaction rates with time and temperature. In addition, the non-Arrhenius kinetics technique eliminates the need for a descriptive reaction scheme that is typically computationally demanding, and instead focuses on the overall changes in the carbon oxides, oil, water and heat occurring at any time. Significantly, less tuning of parameters is required to match laboratory experiments because laboratory observations are easier to enforce.","PeriodicalId":11015,"journal":{"name":"Day 1 Mon, September 24, 2018","volume":"21 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78092798","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}
Dharmendra Kumar, A. Ghassemi, S. Riley, Brendan Elliott
Well-to-well interference or communication between the production or "Parent" well and the infill or "child" well is one of the main concern in horizontal wells refracturing, which results in a decrease of productivity of both the wells. Many field observations have demonstrated that the "child" well fractures could have a tendency to propagate towards the "parent" well resulting in well-to-well interference or "frac-hits" issues. This paper presents a geomechanical perspective to better understand the problem of "frac-hits" in horizontal well refracturing and to design solutions for it using geomechanics analysis and modeling. The numerical analysis is based on a fully coupled 3D model "GeoFrac3D" with the capabilities to simulate multistage fracturing of multiple horizontal wells. The model fully couples pore pressure to stresses and allows for dynamic modeling of production/injection and fracture propagation. The modeling results show that production from the parent well gives rise to a non-uniform reduction of the reservoir pore pressure around the production fractures leading to anisotropic decrease of the reservoir total stresses which may result in stress reorientation or reversal. The decrease of total stresses in the vicinity of the parent well fractures creates an attraction zone for the child well fractures. The child well fractures have a tendency for asymmetric growth towards the lower stress zone. The impact on the parent and child well production and the risk of "frac-hits" will vary with the reservoir stress regime and production time. Optimizing fracture and well spacing, fluid viscosity, and the timing of refracturing can help to minimize problems. The simulation results demonstrate that the risks of "frac-hits" issue can be mitigated by re-pressurization of the parent well before child well. Traditional methods of refracturing simulation usually use two different codes to solve the problem and mostly use stress analysis rather than explicit fracture propagation. The model used in this study can simulate both aspects of the problem i.e., the reservoir depletion analysis and the subsequent child well fracturing.
{"title":"Geomechanical Analysis of Frac-Hits Using a 3D Poroelastic Hydraulic Fracture Model","authors":"Dharmendra Kumar, A. Ghassemi, S. Riley, Brendan Elliott","doi":"10.2118/191491-MS","DOIUrl":"https://doi.org/10.2118/191491-MS","url":null,"abstract":"\u0000 Well-to-well interference or communication between the production or \"Parent\" well and the infill or \"child\" well is one of the main concern in horizontal wells refracturing, which results in a decrease of productivity of both the wells. Many field observations have demonstrated that the \"child\" well fractures could have a tendency to propagate towards the \"parent\" well resulting in well-to-well interference or \"frac-hits\" issues. This paper presents a geomechanical perspective to better understand the problem of \"frac-hits\" in horizontal well refracturing and to design solutions for it using geomechanics analysis and modeling. The numerical analysis is based on a fully coupled 3D model \"GeoFrac3D\" with the capabilities to simulate multistage fracturing of multiple horizontal wells. The model fully couples pore pressure to stresses and allows for dynamic modeling of production/injection and fracture propagation. The modeling results show that production from the parent well gives rise to a non-uniform reduction of the reservoir pore pressure around the production fractures leading to anisotropic decrease of the reservoir total stresses which may result in stress reorientation or reversal. The decrease of total stresses in the vicinity of the parent well fractures creates an attraction zone for the child well fractures. The child well fractures have a tendency for asymmetric growth towards the lower stress zone. The impact on the parent and child well production and the risk of \"frac-hits\" will vary with the reservoir stress regime and production time. Optimizing fracture and well spacing, fluid viscosity, and the timing of refracturing can help to minimize problems. The simulation results demonstrate that the risks of \"frac-hits\" issue can be mitigated by re-pressurization of the parent well before child well. Traditional methods of refracturing simulation usually use two different codes to solve the problem and mostly use stress analysis rather than explicit fracture propagation. The model used in this study can simulate both aspects of the problem i.e., the reservoir depletion analysis and the subsequent child well fracturing.","PeriodicalId":11015,"journal":{"name":"Day 1 Mon, September 24, 2018","volume":"11 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84277037","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. Strand, Jarmo Kouko, A. Oksanen, K. Salminen, A. Ketola, E. Retulainen, A. Sundberg
The procedures used in restraining the web during drying will severely affect paper properties. In this work, the main differences between restrained drying and unrestrained drying on paper properties were identified. The mechanical properties of paper were studied as a function of low-consistency mechanical refining energy; wet-end additions of carboxymethyl cellulose (CMC) with cationic starches; as well as spray addition of alginate, chitosan, and cationic guar gum. After restrained drying, the tensile index and tensile stiffness increased with increasing refining energy, but the elongation at break was severely limited. After unrestrained drying, the elongation at break increased linearly with increasing refining energy. However, unrestrained drying also resulted in significantly lower tensile index and tensile stiffness values. After restrained drying, the largest increases in tensile index and stiffness were obtained by sequential wet-end addition of CMC and cationic starches. Certain combinations could mitigate all of the decrease in tensile index from unrestrained drying, while maintaining the distinctively high elongation potential of the paper. Wet-end addition of CMC and cationic starches could mitigate some of the decrease in tensile stiffness, but not completely. Spray addition of alginate, chitosan, or cationic guar gum increased the tensile index after both restrained and unrestrained drying. Spray addition of alginate resulted in significant increases in elongation at break and two-dimensional formability of the handsheets after unrestrained drying. After restrained drying, the tensile stiffness increased after spray addition of all of the different polysaccharides. After unrestrained drying, however, stiffness was unaffected by all of the tested polysaccharide spray additions. The same pulp treatment/additives will increase either stiffness or stretch, depending on the drying technique, but both properties could not be maximized simultaneously.
{"title":"Boosting the elongation potential of paper by mechanical refining and additives","authors":"A. Strand, Jarmo Kouko, A. Oksanen, K. Salminen, A. Ketola, E. Retulainen, A. Sundberg","doi":"10.32964/TJ17.09.489","DOIUrl":"https://doi.org/10.32964/TJ17.09.489","url":null,"abstract":"The procedures used in restraining the web during drying will severely affect paper properties. In this work, the main differences between restrained drying and unrestrained drying on paper properties were identified. The mechanical properties of paper were studied as a function of low-consistency mechanical refining energy; wet-end additions of carboxymethyl cellulose (CMC) with cationic starches; as well as spray addition of alginate, chitosan, and cationic guar gum. After restrained drying, the tensile index and tensile stiffness increased with increasing refining energy, but the elongation at break was severely limited. After unrestrained drying, the elongation at break increased linearly with increasing refining energy. However, unrestrained drying also resulted in significantly lower tensile index and tensile stiffness values. After restrained drying, the largest increases in tensile index and stiffness were obtained by sequential wet-end addition of CMC and cationic starches. Certain combinations could mitigate all of the decrease in tensile index from unrestrained drying, while maintaining the distinctively high elongation potential of the paper. Wet-end addition of CMC and cationic starches could mitigate some of the decrease in tensile stiffness, but not completely. Spray addition of alginate, chitosan, or cationic guar gum increased the tensile index after both restrained and unrestrained drying. Spray addition of alginate resulted in significant increases in elongation at break and two-dimensional formability of the handsheets after unrestrained drying. After restrained drying, the tensile stiffness increased after spray addition of all of the different polysaccharides. After unrestrained drying, however, stiffness was unaffected by all of the tested polysaccharide spray additions. The same pulp treatment/additives will increase either stiffness or stretch, depending on the drying technique, but both properties could not be maximized simultaneously.","PeriodicalId":11015,"journal":{"name":"Day 1 Mon, September 24, 2018","volume":"5 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-09-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83387952","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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