Nayung Galih Proboseno, Aris Nur Atmiaji, A. Suryana, Rudhy Setiawan, Adhyasa Humam Haryaputra, Taufik Fansuri, Masrul Ali Jusda
The evaluation of flow profile in the wellbore system is an important part of oil & gas field development. Leaks that occur in or behind the production casing is not only potentially causes safety and environmental issue but also potentially misjudgments of production performance analysis and the estimation of remaining reserve. The flow profile in the wellbore mostly affected by the life cycle of well during drilling phase, completion phase, production or injection phase and restoration phase. One of many well-known technologies applied in oil & gas industries is acoustic leak detection and pressure thermal log. The selection of surveillance technique to identify undesired water flow problem is not only provides more effective result but also carries an acceptable risk in term of the project cost. The objective of this paper is to show how a new approach of acoustic leak detection and pressure thermal surveillance can be used to increase the effectiveness of water shutoff operation in mature oil and gas field. The new approach of dynamic surveillance technique provided the acoustic, pressure and thermal data acquisition along the artificial lift wells can be interpreted. The case studies shows that the undesired water flow in or behind production casing can be identified precisely compared with a conventional method such as cement bond log. As the result, the data interpretation gives a remarkable result both of the successful water shutoff operation and post job production performance. Water significantly can be reduced from 1300 bbl per day to 320 bbl per day and the other hand oil & gas significantly can be increased from 34 boepd to 532 boepd. Moreover, this paper should be beneficial to help all petroleum engineers currently working in mature oilfield not only to identify undesired water flow problem precisely but also develop a comprehensive and effective water shutoff and remediation plan.
{"title":"Increase the Effectiveness of Water Shutoff Operation Using Acoustic Leak Detection and Pressure Thermal Log in Mature Field South Sumatera – Indonesia","authors":"Nayung Galih Proboseno, Aris Nur Atmiaji, A. Suryana, Rudhy Setiawan, Adhyasa Humam Haryaputra, Taufik Fansuri, Masrul Ali Jusda","doi":"10.2118/212934-ms","DOIUrl":"https://doi.org/10.2118/212934-ms","url":null,"abstract":"\u0000 The evaluation of flow profile in the wellbore system is an important part of oil & gas field development. Leaks that occur in or behind the production casing is not only potentially causes safety and environmental issue but also potentially misjudgments of production performance analysis and the estimation of remaining reserve. The flow profile in the wellbore mostly affected by the life cycle of well during drilling phase, completion phase, production or injection phase and restoration phase. One of many well-known technologies applied in oil & gas industries is acoustic leak detection and pressure thermal log. The selection of surveillance technique to identify undesired water flow problem is not only provides more effective result but also carries an acceptable risk in term of the project cost. The objective of this paper is to show how a new approach of acoustic leak detection and pressure thermal surveillance can be used to increase the effectiveness of water shutoff operation in mature oil and gas field.\u0000 The new approach of dynamic surveillance technique provided the acoustic, pressure and thermal data acquisition along the artificial lift wells can be interpreted. The case studies shows that the undesired water flow in or behind production casing can be identified precisely compared with a conventional method such as cement bond log.\u0000 As the result, the data interpretation gives a remarkable result both of the successful water shutoff operation and post job production performance. Water significantly can be reduced from 1300 bbl per day to 320 bbl per day and the other hand oil & gas significantly can be increased from 34 boepd to 532 boepd.\u0000 Moreover, this paper should be beneficial to help all petroleum engineers currently working in mature oilfield not only to identify undesired water flow problem precisely but also develop a comprehensive and effective water shutoff and remediation plan.","PeriodicalId":433466,"journal":{"name":"Day 1 Tue, March 21, 2023","volume":"61 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127242903","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}
At the end of 2020, complex well anomalies were identified in the previously shut-in, highly deviated well A in deepwater Gulf of Mexico. Closely monitored wellbore pressures indicated A/B annulus communication, and remedial slickline diagnostics discovered the tubing was parted between ~4,250 and 4,270 ft measured depth. The abnormal well conditions and the presence of a single barrier on both the A-annulus and B-annulus triggered the well anomaly process, and action was taken to mitigate the risk profile by commencing abandonment operations prior to the start of the hurricane season. The well anomaly risk assessment indicated the highest risk was the single barrier on the B-annulus as it had a history of failures and repairs. The outcome was to attempt to further mitigate the risk profile by commencing zonal isolation operations. To achieve a safe operation, a real-time coiled tubing (CT) downhole measurement system and dynamic interpretation software were used to mitigate the risks involved in accessing the lower section of the parted production tubing, pressure testing the completion, perforating the tubing, confirming the firing of the tubing-conveyed perforating guns, and pumping a balanced cement plug in the tubing and annulus after setting the cement retainer. This study proposes an innovative approach to integrating CT, telemetry, and mechanical wellbore isolation tools to increase operational efficiency. Real-time bottomhole pressure, temperature, and casing collar locator (CCL) measurements proved invaluable by providing the necessary guidance to successfully set the inflatable packer and fire the perforating guns. They also provided pressure confirmation that tubing integrity issues did not allow cement in the A-annulus to escape into the production tubing on to the backside of the CT.
{"title":"Complex Operation to Insert Coiled Tubing Through Parted Production Tubing and Regain Pressure Integrity for Plugging and Abandonment","authors":"Sergio A Rondon Fajardo, E. Adams","doi":"10.2118/212879-ms","DOIUrl":"https://doi.org/10.2118/212879-ms","url":null,"abstract":"\u0000 At the end of 2020, complex well anomalies were identified in the previously shut-in, highly deviated well A in deepwater Gulf of Mexico. Closely monitored wellbore pressures indicated A/B annulus communication, and remedial slickline diagnostics discovered the tubing was parted between ~4,250 and 4,270 ft measured depth.\u0000 The abnormal well conditions and the presence of a single barrier on both the A-annulus and B-annulus triggered the well anomaly process, and action was taken to mitigate the risk profile by commencing abandonment operations prior to the start of the hurricane season.\u0000 The well anomaly risk assessment indicated the highest risk was the single barrier on the B-annulus as it had a history of failures and repairs. The outcome was to attempt to further mitigate the risk profile by commencing zonal isolation operations. To achieve a safe operation, a real-time coiled tubing (CT) downhole measurement system and dynamic interpretation software were used to mitigate the risks involved in accessing the lower section of the parted production tubing, pressure testing the completion, perforating the tubing, confirming the firing of the tubing-conveyed perforating guns, and pumping a balanced cement plug in the tubing and annulus after setting the cement retainer.\u0000 This study proposes an innovative approach to integrating CT, telemetry, and mechanical wellbore isolation tools to increase operational efficiency. Real-time bottomhole pressure, temperature, and casing collar locator (CCL) measurements proved invaluable by providing the necessary guidance to successfully set the inflatable packer and fire the perforating guns. They also provided pressure confirmation that tubing integrity issues did not allow cement in the A-annulus to escape into the production tubing on to the backside of the CT.","PeriodicalId":433466,"journal":{"name":"Day 1 Tue, March 21, 2023","volume":"66 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114131107","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}
Lei Hou, Chong Zhang, Xin Zhi Hou, Yong Jia Dong, Yu Zhao Peng, Vaibhav Gupta, V. Unnikrishnan, Feng Li Wei, Lin Guo Li, Feng Yi Wu, Yang Ming Huang, Zhen Hua, Lin Hou Li
A workover campaign in low bottomhole pressure gas wells in China South Sea was planned, where a through tubing retrievable inflatable bridge plug (TTIRBP) was chosen to provide zonal isolation. Challenging circumstances include zero fluid contamination allowed, small through tubing restriction as opposed to large setting ID, shallow working depth and tight working schedule to complete the workover activity during the typhoon season. To mitigate the fluid contamination challenge, Nitrogen-driven setting of TTIRBP was selected. Through Tubing Intervention (TTI) services were safely and successfully completed by nitrogen-driven in all six wells via coiled tubing deployment and met the customer workover schedule deadline. After that, these gas wells were recovered to the same initial production rate quickly and efficiently. This paper will provide operational details for the 6 wells in this campaign. These methods are described in detail to share the valuable experience for readers’ similar application.
{"title":"Thru Tubing Inflatable Retrievable Bridge Plug Deployed on Coiled Tubing in Low Pressure Gas Wells with ID Restrictions for Workover Operations - A Case History from China","authors":"Lei Hou, Chong Zhang, Xin Zhi Hou, Yong Jia Dong, Yu Zhao Peng, Vaibhav Gupta, V. Unnikrishnan, Feng Li Wei, Lin Guo Li, Feng Yi Wu, Yang Ming Huang, Zhen Hua, Lin Hou Li","doi":"10.2118/212901-ms","DOIUrl":"https://doi.org/10.2118/212901-ms","url":null,"abstract":"\u0000 A workover campaign in low bottomhole pressure gas wells in China South Sea was planned, where a through tubing retrievable inflatable bridge plug (TTIRBP) was chosen to provide zonal isolation.\u0000 Challenging circumstances include zero fluid contamination allowed, small through tubing restriction as opposed to large setting ID, shallow working depth and tight working schedule to complete the workover activity during the typhoon season. To mitigate the fluid contamination challenge, Nitrogen-driven setting of TTIRBP was selected.\u0000 Through Tubing Intervention (TTI) services were safely and successfully completed by nitrogen-driven in all six wells via coiled tubing deployment and met the customer workover schedule deadline. After that, these gas wells were recovered to the same initial production rate quickly and efficiently.\u0000 This paper will provide operational details for the 6 wells in this campaign. These methods are described in detail to share the valuable experience for readers’ similar application.","PeriodicalId":433466,"journal":{"name":"Day 1 Tue, March 21, 2023","volume":"125 ","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"120878190","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}
An oil well in Colorado had bradenhead pressure of 700 psi on the 9-5/8 in × 5-1/2 in annulus, prompting remediation to get bradenhead pressure below the 200-psi threshold set by the Colorado Oil and Gas Conservation Commission (COGCC) to resume production. A biomineralization company was contracted by an operator in Colorado to apply their proprietary biomineralization technology to the well. Cement bond logs were used to identify a micro annulus around 3,050 ft. The well was prepared by setting a bridge plug at 3,062 ft, perforating at 3,056 ft and 3,052 ft, and running tubing to the depth of the bottom perforation. Biomineralizing fluids were then pumped into the well, where they formed crystalline calcium carbonate in the micro annuli. After 36 hours of treatment, the injection rate dropped by several orders of magnitude. Subsequent monitoring by a state regulator determined bradenhead pressure had been eliminated and the well passed a mechanical integrity test without any additional intervention, allowing production to promptly resume.
{"title":"Eliminating Bradenhead Pressure Using Novel Biomineralization Technology","authors":"Dwight Randy Hiebert, J. Griffin","doi":"10.2118/212893-ms","DOIUrl":"https://doi.org/10.2118/212893-ms","url":null,"abstract":"An oil well in Colorado had bradenhead pressure of 700 psi on the 9-5/8 in × 5-1/2 in annulus, prompting remediation to get bradenhead pressure below the 200-psi threshold set by the Colorado Oil and Gas Conservation Commission (COGCC) to resume production.\u0000 A biomineralization company was contracted by an operator in Colorado to apply their proprietary biomineralization technology to the well. Cement bond logs were used to identify a micro annulus around 3,050 ft. The well was prepared by setting a bridge plug at 3,062 ft, perforating at 3,056 ft and 3,052 ft, and running tubing to the depth of the bottom perforation. Biomineralizing fluids were then pumped into the well, where they formed crystalline calcium carbonate in the micro annuli.\u0000 After 36 hours of treatment, the injection rate dropped by several orders of magnitude. Subsequent monitoring by a state regulator determined bradenhead pressure had been eliminated and the well passed a mechanical integrity test without any additional intervention, allowing production to promptly resume.","PeriodicalId":433466,"journal":{"name":"Day 1 Tue, March 21, 2023","volume":"42 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131976733","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}
Hassan Basim Alnasser, Ugochukwu Maria Okeke, Zhiheng Zhang, Ron van der Veen, S. Chishti, S. Umirshin
In recent years, multilateral wells have become more predominant enabling either improved recovery or injectivity depending on the well type. The process of timely accessing the correct lateral with coiled tubing (CT) is still one of the greatest challenges relative to the well intervention. This paper presents a case history in which a flawless 2.375-in CT intervention was performed to stimulate laterals with a proprietary multilateral entry bottom hole assembly (BHA) that steered the CT efficiently into the laterals. The injector well has a natural and un-natural lateral, both of which required stimulation. A proprietary hydraulic multilateral entry tool was selected for the job which reliably locates and enters multiple lateral junctions in a single run. The special working mechanism of the tool circumvents any need for an electrical control or steering system. Along with this tool, a casing collar locator (CCL) was incorporated into the BHA, powered by a proprietary CT conductor telemetry system. Real time data enabled confirmation relative to access into the correct lateral to save time without the need to tag the bottom. A gamma ray (GR) sub can also be incorporated into the BHA to correlate depth where needed. A major challenge for multilateral intervention is time on location. The multilateral entry tool searches for the lateral by rotating 360° until it reaches the desired kick off angle which is confirmed by a surface pressure indication signifying that the correct lateral has been located. The simple yet effective operational mechanism of the multilateral tool allows each lateral to be found and entered in less than 30 minutes once it is positioned at the window. Depth correlation is confirmed with use of either the CCL or GR subs or a combination of the two and the multilateral entry tool is resettable easily by pressurizing, which enables any number of laterals to be located & stimulated. The job was completed safely as per program with more than 4,000 bbl of acid pumped to stimulate both the laterals. The entire operation was conducted efficiently, flawlessly, and post injectivity results of the stimulation resulted in significant incremental injection drainage capability. This combination of BHA's options and the efficient mechanism of the multilateral entry tool to find and enter multiple laterals quickly and reset without the need to pull out of hole, enables the Operator to intervene in any number of branches of a multilateral well in a timely and efficient manner. This is a very important case history for other complex multilateral wells in the region which could benefit from this technology and approach
{"title":"Efficient and Reliable Multilateral Coiled Tubing Intervention Technique for Acid Stimulation: A Case History in the Middle East","authors":"Hassan Basim Alnasser, Ugochukwu Maria Okeke, Zhiheng Zhang, Ron van der Veen, S. Chishti, S. Umirshin","doi":"10.2118/212921-ms","DOIUrl":"https://doi.org/10.2118/212921-ms","url":null,"abstract":"\u0000 In recent years, multilateral wells have become more predominant enabling either improved recovery or injectivity depending on the well type. The process of timely accessing the correct lateral with coiled tubing (CT) is still one of the greatest challenges relative to the well intervention. This paper presents a case history in which a flawless 2.375-in CT intervention was performed to stimulate laterals with a proprietary multilateral entry bottom hole assembly (BHA) that steered the CT efficiently into the laterals.\u0000 The injector well has a natural and un-natural lateral, both of which required stimulation. A proprietary hydraulic multilateral entry tool was selected for the job which reliably locates and enters multiple lateral junctions in a single run. The special working mechanism of the tool circumvents any need for an electrical control or steering system. Along with this tool, a casing collar locator (CCL) was incorporated into the BHA, powered by a proprietary CT conductor telemetry system. Real time data enabled confirmation relative to access into the correct lateral to save time without the need to tag the bottom. A gamma ray (GR) sub can also be incorporated into the BHA to correlate depth where needed.\u0000 A major challenge for multilateral intervention is time on location. The multilateral entry tool searches for the lateral by rotating 360° until it reaches the desired kick off angle which is confirmed by a surface pressure indication signifying that the correct lateral has been located. The simple yet effective operational mechanism of the multilateral tool allows each lateral to be found and entered in less than 30 minutes once it is positioned at the window. Depth correlation is confirmed with use of either the CCL or GR subs or a combination of the two and the multilateral entry tool is resettable easily by pressurizing, which enables any number of laterals to be located & stimulated. The job was completed safely as per program with more than 4,000 bbl of acid pumped to stimulate both the laterals. The entire operation was conducted efficiently, flawlessly, and post injectivity results of the stimulation resulted in significant incremental injection drainage capability.\u0000 This combination of BHA's options and the efficient mechanism of the multilateral entry tool to find and enter multiple laterals quickly and reset without the need to pull out of hole, enables the Operator to intervene in any number of branches of a multilateral well in a timely and efficient manner. This is a very important case history for other complex multilateral wells in the region which could benefit from this technology and approach","PeriodicalId":433466,"journal":{"name":"Day 1 Tue, March 21, 2023","volume":"143 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122868760","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}
Juan Jose Nobile Blanco, S. Prabhakaran, Shiwanshu Shiwan, Chirag Rathod, David Ting
An offshore production well was out of operation after unsuccessful inflow tests. A remedial work plan was designed, but the execution resulted in severe damage to the top of the flowtube inside the Subsurface Safety Valve (SSSV), which was bent over and preventing production. Wireline conveyed mechanical intervention was performed with robotic tools to mill the obstruction and regain full bore access. Downhole hardware milling is a common technology; however, a thorough process must be followed in order to succeed. The following factors were among those to be considered: well configuration (completion schematic and restrictions); the material of the flowtube (9CR-1MO Martensitic Steel); the risk of damaging the surrounding area; the risk of rotating the whole assembly while milling; and the risk of getting stuck with the e-line Bottom Hole Assembly (BHA). The milling intervention program was drafted taking into consideration different scenarios including contingencies. E-line conveyed robotic milling intervention was the preferred option due to the urgency of the operation and high accuracy required to ensure the SSSV was left operational after milling. The robotic toolstring was first deployed for a drift run. Subsequent diagnostic runs were executed to help the team understand the downhole situation, adjust the operation plan and to test the performance of the tool downhole. Finally, the milling run was conducted showing a clear signature on the acquisition system, providing the parties involved with certainty regarding the outcome. A camera run was performed to verify the conditions of the operational area after milling. The job was executed in a total of four runs as per the program. Furthermore, the milling time itself was only 17 minutes. The complete removal of the damaged section of flowtube allowed the client to restore production immediately after testing the well integrity, with the SSSV fully functional. This paper describes the complex yet efficient operation where a robotic milling tool, conveyed by e-line, was able to remove a critical downhole obstruction and restore production while preserving all safety features of the well, thus preventing a complex workover operation. The in-depth preparation, followed by a methodical execution, allowed oil production to be resumed in this well.
{"title":"Production and Well Access Restored After a Successful Subsurface Safety Valve Flowtube Milling on E-line, Preventing Major Rig Workover","authors":"Juan Jose Nobile Blanco, S. Prabhakaran, Shiwanshu Shiwan, Chirag Rathod, David Ting","doi":"10.2118/212884-ms","DOIUrl":"https://doi.org/10.2118/212884-ms","url":null,"abstract":"\u0000 An offshore production well was out of operation after unsuccessful inflow tests. A remedial work plan was designed, but the execution resulted in severe damage to the top of the flowtube inside the Subsurface Safety Valve (SSSV), which was bent over and preventing production. Wireline conveyed mechanical intervention was performed with robotic tools to mill the obstruction and regain full bore access.\u0000 Downhole hardware milling is a common technology; however, a thorough process must be followed in order to succeed. The following factors were among those to be considered: well configuration (completion schematic and restrictions); the material of the flowtube (9CR-1MO Martensitic Steel); the risk of damaging the surrounding area; the risk of rotating the whole assembly while milling; and the risk of getting stuck with the e-line Bottom Hole Assembly (BHA). The milling intervention program was drafted taking into consideration different scenarios including contingencies.\u0000 E-line conveyed robotic milling intervention was the preferred option due to the urgency of the operation and high accuracy required to ensure the SSSV was left operational after milling. The robotic toolstring was first deployed for a drift run. Subsequent diagnostic runs were executed to help the team understand the downhole situation, adjust the operation plan and to test the performance of the tool downhole. Finally, the milling run was conducted showing a clear signature on the acquisition system, providing the parties involved with certainty regarding the outcome. A camera run was performed to verify the conditions of the operational area after milling. The job was executed in a total of four runs as per the program. Furthermore, the milling time itself was only 17 minutes. The complete removal of the damaged section of flowtube allowed the client to restore production immediately after testing the well integrity, with the SSSV fully functional.\u0000 This paper describes the complex yet efficient operation where a robotic milling tool, conveyed by e-line, was able to remove a critical downhole obstruction and restore production while preserving all safety features of the well, thus preventing a complex workover operation. The in-depth preparation, followed by a methodical execution, allowed oil production to be resumed in this well.","PeriodicalId":433466,"journal":{"name":"Day 1 Tue, March 21, 2023","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130199319","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}
Previous work has shown that large force waves traveling through the coiled tubing (CT) correlated with extended reach tool (ERT) operations can generate axial vibration harmonics in the CT that may lead to CT failures. This paper documents continued work which has shown that the surface equipment also has natural frequencies of vibration. When these natural frequencies are multiples of the ERT frequency, the ERT stimulates the surface equipment vibration modes.
{"title":"Lessons from High-Speed Data Acquisition on Frac Plug Milling Operations","authors":"K. Newman, P. Kelleher","doi":"10.2118/212904-ms","DOIUrl":"https://doi.org/10.2118/212904-ms","url":null,"abstract":"\u0000 Previous work has shown that large force waves traveling through the coiled tubing (CT) correlated with extended reach tool (ERT) operations can generate axial vibration harmonics in the CT that may lead to CT failures. This paper documents continued work which has shown that the surface equipment also has natural frequencies of vibration. When these natural frequencies are multiples of the ERT frequency, the ERT stimulates the surface equipment vibration modes.","PeriodicalId":433466,"journal":{"name":"Day 1 Tue, March 21, 2023","volume":"24 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127140132","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. Craig, B. Lindsey, K. Elliott, E. Arriaga, Finlay Thom, Anjan Blatter
This paper will present an update on the operational benefits of utilizing anti-cracking inhibitors in sour wells. Multiple papers have shared the details of a Joint Industry Project which resulted in a one-size-fits-all fatigue derating factor by the service supplier. In recent years, additional testing has challenged that practice and a greater variety of improved derating factors are utilized in fatigue tracking software. The testing process of exposing samples to sour conditions for 72 hours and conducting bend fatigue testing post exposure remains the method used in this paper. The process updated the JIP practice of one-time coating of the sample with the addition of an anti-cracking inhibitor to the sour fluid. This update more closely replicates real-world operations. In addition, there was a greater focus on the test sample size, stress and strain to reduce fatigue testing time and reduce the effects of any outgassing leading to a more accurate and repeatable test. A comparison of three typical test methods will be presented: non-inhibited sour tests by the original equipment manufacturer, inhibited field specific partial pressure testing by an operator and globally applicable inhibited testing conducted at the maximum apparatus test level by a service provider. Comparison of prior anti-cracking inhibitor and a North Sea approved inhibitor results will be detailed. The practice for conducting the tests with a high yield material and extending the results to a lower grade material with similar chemistry will be detailed. Note that the results of separate tests conducted on the pipe body and bias welds will be compared and detailed. A brief summary of the service providers record of global sour pipe operations will illustrate these practices have proved suitable in the field. The updated practices and procedures for sour testing have not been shared in prior papers. The improved pipe life will assist the industry with efficient and safe operational planning in sour wells. Finally extending pipe life will reduce the amount of raw steel required for operations and ultimately reducing carbon dioxide emissions, a global challenge from which we can all benefit.
{"title":"Protecting from H2S Damage – Expanding the Knowledge","authors":"S. Craig, B. Lindsey, K. Elliott, E. Arriaga, Finlay Thom, Anjan Blatter","doi":"10.2118/212944-ms","DOIUrl":"https://doi.org/10.2118/212944-ms","url":null,"abstract":"\u0000 This paper will present an update on the operational benefits of utilizing anti-cracking inhibitors in sour wells. Multiple papers have shared the details of a Joint Industry Project which resulted in a one-size-fits-all fatigue derating factor by the service supplier. In recent years, additional testing has challenged that practice and a greater variety of improved derating factors are utilized in fatigue tracking software.\u0000 The testing process of exposing samples to sour conditions for 72 hours and conducting bend fatigue testing post exposure remains the method used in this paper. The process updated the JIP practice of one-time coating of the sample with the addition of an anti-cracking inhibitor to the sour fluid. This update more closely replicates real-world operations. In addition, there was a greater focus on the test sample size, stress and strain to reduce fatigue testing time and reduce the effects of any outgassing leading to a more accurate and repeatable test.\u0000 A comparison of three typical test methods will be presented: non-inhibited sour tests by the original equipment manufacturer, inhibited field specific partial pressure testing by an operator and globally applicable inhibited testing conducted at the maximum apparatus test level by a service provider. Comparison of prior anti-cracking inhibitor and a North Sea approved inhibitor results will be detailed. The practice for conducting the tests with a high yield material and extending the results to a lower grade material with similar chemistry will be detailed. Note that the results of separate tests conducted on the pipe body and bias welds will be compared and detailed. A brief summary of the service providers record of global sour pipe operations will illustrate these practices have proved suitable in the field.\u0000 The updated practices and procedures for sour testing have not been shared in prior papers. The improved pipe life will assist the industry with efficient and safe operational planning in sour wells. Finally extending pipe life will reduce the amount of raw steel required for operations and ultimately reducing carbon dioxide emissions, a global challenge from which we can all benefit.","PeriodicalId":433466,"journal":{"name":"Day 1 Tue, March 21, 2023","volume":"20 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125964384","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
This paper presents the intervention activities performed under high crossflow conditions in Chirag Auto Gas Lift (In-situ GL/Natural GL) completion design where crossflow between the reservoir zones posed a major challenge. Auto Gas Lift design was installed on a few selected wells of the Chirag field due to a lack of conventional gas-lift equipment, compressors, and pipelines. When Auto gas lift wells are shut in, crossflow occurs between the high-pressure gas-bearing zone used to lift the oil and the lower- pressured oil-bearing reservoir zone. The amount of crossflow is controlled by installing a choke (gas lift valve) across the gas bearing zone. On well A completed in August 2020, an oversize Gas Lift Valve was installed which created suboptimal flowing conditions, production deferrals and severe crossflow during shut-in. An intervention activity was carried out to replace the oversized valve in this severe crossflow condition. Installation of a plug was necessary to stop the cross-flow during the valve change-out operation but proved to be very challenging because the force from the crossflow - a rushing mixture of gas/sand - would be pushing against the cross-sectional area of any tool that is to be RIH. This paper describes the multiple options that can be worked out via modelling to define the optimal approach for successful intervention operations in high crossflow environments. The rate of cross-flow in the well can limit well intervention options. Due to piston force created by cross- flow, conventional methods of reservoir isolation are not always feasible, hence deployment method needs to be thoroughly analyzed during job planning. Several ways of reservoir isolation methods – utilizing slickline or e-line methodology have been cross-checked through rigorous modelling and collaboration with the contractors. This modelling revealed that well A crossflow conditions exceeded the safe operating limits of the Slickline wire and would introduce significant damages to the e-line wire due to the build-up piston force on the plug as it expands. After a few iterations, the optimized solution was identified as having an anchor that would be set before the plug and allow the passage of the gas flow through it. This intervention activity was carried out successfully on Well A as a result of the mutual efforts of all partners. The article also discusses the option of killing the well as a last resort to proceed with a required intervention job.
{"title":"Interventions in High Cross-Flow / Auto Gas Lift Well in Chirag Field, Caspian Region","authors":"R. Adilov, R. Karimova, Javid Aliyev","doi":"10.2118/212929-ms","DOIUrl":"https://doi.org/10.2118/212929-ms","url":null,"abstract":"\u0000 This paper presents the intervention activities performed under high crossflow conditions in Chirag Auto Gas Lift (In-situ GL/Natural GL) completion design where crossflow between the reservoir zones posed a major challenge. Auto Gas Lift design was installed on a few selected wells of the Chirag field due to a lack of conventional gas-lift equipment, compressors, and pipelines. When Auto gas lift wells are shut in, crossflow occurs between the high-pressure gas-bearing zone used to lift the oil and the lower- pressured oil-bearing reservoir zone. The amount of crossflow is controlled by installing a choke (gas lift valve) across the gas bearing zone. On well A completed in August 2020, an oversize Gas Lift Valve was installed which created suboptimal flowing conditions, production deferrals and severe crossflow during shut-in. An intervention activity was carried out to replace the oversized valve in this severe crossflow condition. Installation of a plug was necessary to stop the cross-flow during the valve change-out operation but proved to be very challenging because the force from the crossflow - a rushing mixture of gas/sand - would be pushing against the cross-sectional area of any tool that is to be RIH. This paper describes the multiple options that can be worked out via modelling to define the optimal approach for successful intervention operations in high crossflow environments.\u0000 The rate of cross-flow in the well can limit well intervention options. Due to piston force created by cross- flow, conventional methods of reservoir isolation are not always feasible, hence deployment method needs to be thoroughly analyzed during job planning. Several ways of reservoir isolation methods – utilizing slickline or e-line methodology have been cross-checked through rigorous modelling and collaboration with the contractors. This modelling revealed that well A crossflow conditions exceeded the safe operating limits of the Slickline wire and would introduce significant damages to the e-line wire due to the build-up piston force on the plug as it expands. After a few iterations, the optimized solution was identified as having an anchor that would be set before the plug and allow the passage of the gas flow through it. This intervention activity was carried out successfully on Well A as a result of the mutual efforts of all partners. The article also discusses the option of killing the well as a last resort to proceed with a required intervention job.","PeriodicalId":433466,"journal":{"name":"Day 1 Tue, March 21, 2023","volume":"31 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124171323","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}
Laurie S. Duthie, Muhammad Awwadh Harthi, Hussain Saiood, O. Afif
The advantages of drilling extended reach wells (ERW’s) are well known; increased reservoir contact, reduced surface footprint and less wells drilled. Although the benefits of drilling these wells is clear, it is also essential to have the ability to conduct well intervention throughout the life of the well. Matrix acid stimulation and production logging are critically important well intervention operations for efficient reservoir management. Coiled tubing (CT) is commonly deployed in ERW’s to perform these intervention operations. For open hole ERW’s, the success of the operation is often directly correlated to the length of the lateral covered. For ERW’s that can exceed 30,000 ft, the challenges to reach total depth (TD) can almost be insurmountable in terms of overcoming the high frictional forces acting against the CT. The level of difficulty is further magnified covering open sections often greater than 10,000 ft, where additional frictional forces are present from the rock, high dogleg severity and well trajectory. High bottom hole temperature along with high H2S & CO2 levels pose further challenges. Formation damage after drilling may result in serious production and therefore economic consequences and it is imperative to restore reservoir permeability along the complete interval with accurate treatment placement. The same challenges are present for logging operations where the main objective is to determine the flow profile along the entire open hole section. To achieve the main objectives, a comprehensive approach is taken for these well intervention operations. Custom designed technologies have been developed to increase the open hole coverage achieved to provide good zonal coverage in matrix acid treatments and also a clearer understanding of multiphase flow from the formation during production logging. Technologies developed specifically to tackle these challenges are hydraulically powered CT tractors that can deliver up to 14,000 lbs pulling force and mechanical agitator tools that effectively reduce the total friction coefficient. Other technologies employed are a downhole compression/tension sub to monitor downhole performance in real time to enhance operational decision making. To extend the ultimate reach, certain techniques can add a few thousand feet in coverage. These techniques include high pressure jetting to clean out the horizontal section of the cased hole to lower the friction, strategically deploying friction reducer and using momentum assiduously. These new technologies and applied techniques opens the window to ultimately meeting the goals of improved well surveillance and treatment in long horizontal laterals. Creative solutions have been core to inventing the best fit for purpose technologies, with great leaps having been made through pioneering technologies to extend CT reach in these extreme conditions.
{"title":"The Vital Role of Well Intervention Technologies and Techniques in Pushing the Boundaries in Extreme Well Completions","authors":"Laurie S. Duthie, Muhammad Awwadh Harthi, Hussain Saiood, O. Afif","doi":"10.2118/212928-ms","DOIUrl":"https://doi.org/10.2118/212928-ms","url":null,"abstract":"\u0000 The advantages of drilling extended reach wells (ERW’s) are well known; increased reservoir contact, reduced surface footprint and less wells drilled. Although the benefits of drilling these wells is clear, it is also essential to have the ability to conduct well intervention throughout the life of the well. Matrix acid stimulation and production logging are critically important well intervention operations for efficient reservoir management.\u0000 Coiled tubing (CT) is commonly deployed in ERW’s to perform these intervention operations. For open hole ERW’s, the success of the operation is often directly correlated to the length of the lateral covered. For ERW’s that can exceed 30,000 ft, the challenges to reach total depth (TD) can almost be insurmountable in terms of overcoming the high frictional forces acting against the CT. The level of difficulty is further magnified covering open sections often greater than 10,000 ft, where additional frictional forces are present from the rock, high dogleg severity and well trajectory. High bottom hole temperature along with high H2S & CO2 levels pose further challenges. Formation damage after drilling may result in serious production and therefore economic consequences and it is imperative to restore reservoir permeability along the complete interval with accurate treatment placement. The same challenges are present for logging operations where the main objective is to determine the flow profile along the entire open hole section.\u0000 To achieve the main objectives, a comprehensive approach is taken for these well intervention operations. Custom designed technologies have been developed to increase the open hole coverage achieved to provide good zonal coverage in matrix acid treatments and also a clearer understanding of multiphase flow from the formation during production logging. Technologies developed specifically to tackle these challenges are hydraulically powered CT tractors that can deliver up to 14,000 lbs pulling force and mechanical agitator tools that effectively reduce the total friction coefficient. Other technologies employed are a downhole compression/tension sub to monitor downhole performance in real time to enhance operational decision making. To extend the ultimate reach, certain techniques can add a few thousand feet in coverage. These techniques include high pressure jetting to clean out the horizontal section of the cased hole to lower the friction, strategically deploying friction reducer and using momentum assiduously.\u0000 These new technologies and applied techniques opens the window to ultimately meeting the goals of improved well surveillance and treatment in long horizontal laterals. Creative solutions have been core to inventing the best fit for purpose technologies, with great leaps having been made through pioneering technologies to extend CT reach in these extreme conditions.","PeriodicalId":433466,"journal":{"name":"Day 1 Tue, March 21, 2023","volume":"351 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116359180","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}
京公网安备 11010802042870号
京ICP备2023020795号-1
扫码关注我们
求助内容：
应助结果提醒方式：