Langbauer Clemens, F. Rudolf, Hartl Manuel, H. Herbert
In days where the oil price is low, cost optimization is of vital importance. Especially in mature oil fields, the reduction of lifting costs by increasing the mean time between failure and the overall efficiency helps to stay economical and increase the final recovery factor. Today a significant portion of artificially lifted wells use sucker rod pumping systems. Although its efficiency is in the upper range, compared to other artificial lift systems, there is room for improvement and system optimization. This paper presents the benefits of the field-tested Sucker Rod Anti-Buckling System (SRABS), which can entirely prevent compressive loads from the sucker rod string by a redesign of the standing valve, the advantageous use of the dynamic liquid level, and the on a case-by-case basis application of a tension mass. This results in complete buckling prevention and a reduction of the overall stress in the sucker rod string. The resulting reduction in the number of well interventions in combination with the higher overall pumping efficiency prolongs economic production in mature oil fields, even in times of low oil prices. The analysis of SRABS, using simulations, showed a significant increase in the overall efficiency. The SRABS performance and wear tests under large-scale conditions are performed at the Montanuniversitaet Leoben's Pump Testing Facility and in the field. The self-developed Pump Testing Facility can simulate the conditions of a 500 m deep well, including the effects of dynamic liquid pressure and temperature. Testing of SRABS has identified major benefits in comparison to standard sucker rod pumps. The results of intensive testing are used to optimize the geometry of the pump body itself and to improve the wear resistance by selecting optimal materials for the individual pump components. SRABS itself can be applied within every sucker rod pumping system; the installation is as convenient as for a standard pump, and manufacturing costs are comparable with those of a standard pump. This paper shows the high performance of the SRABS pumping system in comparison to a standard sucker rod pump.
{"title":"Sucker Rod Anti-Buckling System to Enable Cost-Effective Oil Production","authors":"Langbauer Clemens, F. Rudolf, Hartl Manuel, H. Herbert","doi":"10.2118/191865-MS","DOIUrl":"https://doi.org/10.2118/191865-MS","url":null,"abstract":"\u0000 In days where the oil price is low, cost optimization is of vital importance. Especially in mature oil fields, the reduction of lifting costs by increasing the mean time between failure and the overall efficiency helps to stay economical and increase the final recovery factor. Today a significant portion of artificially lifted wells use sucker rod pumping systems. Although its efficiency is in the upper range, compared to other artificial lift systems, there is room for improvement and system optimization.\u0000 This paper presents the benefits of the field-tested Sucker Rod Anti-Buckling System (SRABS), which can entirely prevent compressive loads from the sucker rod string by a redesign of the standing valve, the advantageous use of the dynamic liquid level, and the on a case-by-case basis application of a tension mass. This results in complete buckling prevention and a reduction of the overall stress in the sucker rod string.\u0000 The resulting reduction in the number of well interventions in combination with the higher overall pumping efficiency prolongs economic production in mature oil fields, even in times of low oil prices. The analysis of SRABS, using simulations, showed a significant increase in the overall efficiency. The SRABS performance and wear tests under large-scale conditions are performed at the Montanuniversitaet Leoben's Pump Testing Facility and in the field. The self-developed Pump Testing Facility can simulate the conditions of a 500 m deep well, including the effects of dynamic liquid pressure and temperature. Testing of SRABS has identified major benefits in comparison to standard sucker rod pumps.\u0000 The results of intensive testing are used to optimize the geometry of the pump body itself and to improve the wear resistance by selecting optimal materials for the individual pump components. SRABS itself can be applied within every sucker rod pumping system; the installation is as convenient as for a standard pump, and manufacturing costs are comparable with those of a standard pump. This paper shows the high performance of the SRABS pumping system in comparison to a standard sucker rod pump.","PeriodicalId":11182,"journal":{"name":"Day 3 Thu, October 25, 2018","volume":"45 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-10-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73422409","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}
Azfar Israa Abu Bakar, M Zul Afiq Ali Jabris, H. A. Rahman, Bakhtiyor Abdullaev, Khairul Nizam Idris, A. Kamis, Zainuddin Yusop, J. C. Kok, Muhammad Faris Kamaludin, M. Z. Zakaria, Nurul Nadia Saiful Mulok
Field B, located offshore Malaysia is heavily reliant on gas lift due to the high water cut behavior of the reservoir coupled with low-medium reservoir pressure. The field faces a challenge to efficiently execute production enhancement activities due to its low effective man-hour, a drawback of unmanned operation philosophy. The recent oil price downturn further exacerbates the limitation and calls for an innovative approach to continue the effort for maximizing oil recovery. As majority of the producing wells are gas-lifted, Gas Lift Optimization (GLOP) is an integral part of Field B's routine production enhancement job. The previous practice of GLOP involves data acquisition process of surface parameters and wireline intervention to collect Bottomhole Pressure (BHP), mainly Flowing Gradient Survey (FGS). Relying on wireline intervention limits the number of gas lift troubleshooting activities due to the low man-hour availability. To address this constraint, CO2 Tracer application was implemented in a campaign to supplement Field B GLOP effort. CO2 Tracer is a technology whereby concentrated CO2 is injected into the gas lift stream via the casing. CO2 returns are collected at the tubing end and utilized to diagnose the gas lift performance. The CO2 Tracer campaign was successfully executed in Platform A, B and C, covering 58 strings within an effective period of 3 months. This achievement is a milestone for the field as it opens a new approach in GLOP data acquisition process. Several advantages observed by executing this campaign is as follows: Multiplication of opportunities generation due to quick and simple operations of CO2 Tracer survey compared to wireline intervention for FGS.Reduction in HSE risks and intervention-related well downtime due to minimal intrusive requirement for well hook-up.Better understanding of complex dual gas lift completion due to simultaneous survey execution.Supplement CO2 baseline measurement for flow assurance monitoring.Quick quality check on gas lift measurement device. This paper will discuss on the challenges at Field B to implement GLOP, technology overview of CO2 tracer, the full cycle process of the CO2 tracer campaign and results of the campaign. Several examples of the findings will also be shared.
{"title":"CO2 Tracer Application to Supplement Gas Lift Optimisation Effort in Offshore Field Sarawak","authors":"Azfar Israa Abu Bakar, M Zul Afiq Ali Jabris, H. A. Rahman, Bakhtiyor Abdullaev, Khairul Nizam Idris, A. Kamis, Zainuddin Yusop, J. C. Kok, Muhammad Faris Kamaludin, M. Z. Zakaria, Nurul Nadia Saiful Mulok","doi":"10.2118/191907-MS","DOIUrl":"https://doi.org/10.2118/191907-MS","url":null,"abstract":"\u0000 Field B, located offshore Malaysia is heavily reliant on gas lift due to the high water cut behavior of the reservoir coupled with low-medium reservoir pressure. The field faces a challenge to efficiently execute production enhancement activities due to its low effective man-hour, a drawback of unmanned operation philosophy. The recent oil price downturn further exacerbates the limitation and calls for an innovative approach to continue the effort for maximizing oil recovery.\u0000 As majority of the producing wells are gas-lifted, Gas Lift Optimization (GLOP) is an integral part of Field B's routine production enhancement job. The previous practice of GLOP involves data acquisition process of surface parameters and wireline intervention to collect Bottomhole Pressure (BHP), mainly Flowing Gradient Survey (FGS). Relying on wireline intervention limits the number of gas lift troubleshooting activities due to the low man-hour availability. To address this constraint, CO2 Tracer application was implemented in a campaign to supplement Field B GLOP effort. CO2 Tracer is a technology whereby concentrated CO2 is injected into the gas lift stream via the casing. CO2 returns are collected at the tubing end and utilized to diagnose the gas lift performance.\u0000 The CO2 Tracer campaign was successfully executed in Platform A, B and C, covering 58 strings within an effective period of 3 months. This achievement is a milestone for the field as it opens a new approach in GLOP data acquisition process. Several advantages observed by executing this campaign is as follows: Multiplication of opportunities generation due to quick and simple operations of CO2 Tracer survey compared to wireline intervention for FGS.Reduction in HSE risks and intervention-related well downtime due to minimal intrusive requirement for well hook-up.Better understanding of complex dual gas lift completion due to simultaneous survey execution.Supplement CO2 baseline measurement for flow assurance monitoring.Quick quality check on gas lift measurement device.\u0000 This paper will discuss on the challenges at Field B to implement GLOP, technology overview of CO2 tracer, the full cycle process of the CO2 tracer campaign and results of the campaign. Several examples of the findings will also be shared.","PeriodicalId":11182,"journal":{"name":"Day 3 Thu, October 25, 2018","volume":"252 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-10-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75843013","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. Bhagavatula, V. Rajagopalan, Suresh Chellappan, Amna Al-Ashwak, M. Elmofti, Alaeldin Boueshi, Waleed K. Eid, A. Allam, Amr Abdel-Baky, John Davis
This paper discusses the successful application of a pillar fracturing technique in a water injection well wherein a major operator previously experienced poor injectivity within the target zone. The aim of the pillar fracturing technique was to achieve the highest possible fracture conductivity to enhance water injectivity for reservoir pressure maintenance. This technique creates infinite conductivity channels with proppant distributed within the fracture as aggregates or groups separated by clean fluid. These proppant groups function as pillars to hold the fracture open and help enable fluid flow in the open channels between proppant pillars. The conductivity of a partially open fracture with proppant pillars can be several orders of magnitude greater than that of a conventional fracture filled with proppant after closure. After a pillar style hydraulic treatment, the propping agent remains in the fracture grouped to form pillars because of the sticky resin that was applied to the proppant just before being blended (intermittently) into the fluid system that was pumped during the treatment. This helps the grains in the resulting pillars to adhere together and help prevent the fracture from entirely closing, forming open conduits for fluid flow. The overall success of this fracturing stimulation treatment depends on the sequenced pumping technique, allowing the propping agent to form proppant aggregates during their placement into the formation. This paper presents the enhanced pillar fracturing technique, pre-job well analysis and design, Minifrac data calibration, and actual pumping operation execution. The well intersects a reservoir with sandstone lithology that had not been fractured previously. The sandstone formation is subdivided into three intervals of 60, 40, and 60-ft thickness, with distinct shale layers separating them. Based on the log interpretations and formation geomechanical analysis, two pillar fracturing stages were determined necessary to treat the entire targeted formation and maintain balanced injectivity in all three intervals. An optimum hydraulic fracturing design was developed and executed to deliver optimal well performance. Actual operational execution involved use of specially designed surface equipment and adhesive enhancement proppant coating to install highly conductive flow paths while maintaining reservoir and proppant pack stability. This resulted in a successful treatment that sustained 16,000 barrels of water injection per day (BWIPD). The successful application of the pillar fracturing technique in this well motivated the operator to extend the pillar fracturing technique to other injector and producer wells.
{"title":"Successful Field Application of Pillar Fracturing Technique in Water Injection Well for Creation of Highly Conductive Conduits","authors":"R. Bhagavatula, V. Rajagopalan, Suresh Chellappan, Amna Al-Ashwak, M. Elmofti, Alaeldin Boueshi, Waleed K. Eid, A. Allam, Amr Abdel-Baky, John Davis","doi":"10.2118/192041-MS","DOIUrl":"https://doi.org/10.2118/192041-MS","url":null,"abstract":"\u0000 This paper discusses the successful application of a pillar fracturing technique in a water injection well wherein a major operator previously experienced poor injectivity within the target zone.\u0000 The aim of the pillar fracturing technique was to achieve the highest possible fracture conductivity to enhance water injectivity for reservoir pressure maintenance. This technique creates infinite conductivity channels with proppant distributed within the fracture as aggregates or groups separated by clean fluid. These proppant groups function as pillars to hold the fracture open and help enable fluid flow in the open channels between proppant pillars. The conductivity of a partially open fracture with proppant pillars can be several orders of magnitude greater than that of a conventional fracture filled with proppant after closure. After a pillar style hydraulic treatment, the propping agent remains in the fracture grouped to form pillars because of the sticky resin that was applied to the proppant just before being blended (intermittently) into the fluid system that was pumped during the treatment. This helps the grains in the resulting pillars to adhere together and help prevent the fracture from entirely closing, forming open conduits for fluid flow. The overall success of this fracturing stimulation treatment depends on the sequenced pumping technique, allowing the propping agent to form proppant aggregates during their placement into the formation.\u0000 This paper presents the enhanced pillar fracturing technique, pre-job well analysis and design, Minifrac data calibration, and actual pumping operation execution. The well intersects a reservoir with sandstone lithology that had not been fractured previously. The sandstone formation is subdivided into three intervals of 60, 40, and 60-ft thickness, with distinct shale layers separating them. Based on the log interpretations and formation geomechanical analysis, two pillar fracturing stages were determined necessary to treat the entire targeted formation and maintain balanced injectivity in all three intervals. An optimum hydraulic fracturing design was developed and executed to deliver optimal well performance. Actual operational execution involved use of specially designed surface equipment and adhesive enhancement proppant coating to install highly conductive flow paths while maintaining reservoir and proppant pack stability. This resulted in a successful treatment that sustained 16,000 barrels of water injection per day (BWIPD).\u0000 The successful application of the pillar fracturing technique in this well motivated the operator to extend the pillar fracturing technique to other injector and producer wells.","PeriodicalId":11182,"journal":{"name":"Day 3 Thu, October 25, 2018","volume":"8 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-10-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83937299","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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