This paper is to introduce the newly developed Anti-Surge valve and control methodology that is capable of mitigating and reducing the magnitude of pressure surges or water hammer phenomenon in liquid pipeline system. The innovative anti-surge valve is a full-bore valve with two circular/concave orifice plates, which can rotate 90 degree in the axial or horizontal interval based on the surge controller indication. Once the surge pressure is being generated in the pipeline, the two circular/concave orifice plates will be in a position, which are particularly able to dissipate the generated pressure waves and decelerate the fluid velocity which as a result can mitigate and reduce the magnitude of pressure surges in the pipeline. By dissipating the generated pressure surge and decelerating the high fluid velocity, the newly developed anti-surge valve is able to protect the pipeline safely and adequately with no external equipment for fluid release. Thus, it can effectively minimize the OPEX and CAPEX for the surge protection system in the upstream oil production facilities or pipelines. The device can enhance the surge protection system by self-dependence, which does not require any external source to be used for equipment operation compared to convention surge protection system using Nitrogen. As a result, it can improve the reliability and efficiency of the surge protection system. This innovative anti-surge valve and control have been officially granted as a new patent in the US Patent and Trademark Office (USPTO) under Patent No. 11,209,842. The new surge control methodology will eliminate water hammering and potential pipeline damages without the use of external equipment to mitigate the surge.
{"title":"Innovative Pressure Surge and Water Hammer Mitigation Control Methodology in Upstream Liquid Pipelines","authors":"Ali Alshehri, S. Salu, Mohamad Soliman","doi":"10.2523/iptc-22809-ea","DOIUrl":"https://doi.org/10.2523/iptc-22809-ea","url":null,"abstract":"\u0000 This paper is to introduce the newly developed Anti-Surge valve and control methodology that is capable of mitigating and reducing the magnitude of pressure surges or water hammer phenomenon in liquid pipeline system. The innovative anti-surge valve is a full-bore valve with two circular/concave orifice plates, which can rotate 90 degree in the axial or horizontal interval based on the surge controller indication. Once the surge pressure is being generated in the pipeline, the two circular/concave orifice plates will be in a position, which are particularly able to dissipate the generated pressure waves and decelerate the fluid velocity which as a result can mitigate and reduce the magnitude of pressure surges in the pipeline. By dissipating the generated pressure surge and decelerating the high fluid velocity, the newly developed anti-surge valve is able to protect the pipeline safely and adequately with no external equipment for fluid release. Thus, it can effectively minimize the OPEX and CAPEX for the surge protection system in the upstream oil production facilities or pipelines. The device can enhance the surge protection system by self-dependence, which does not require any external source to be used for equipment operation compared to convention surge protection system using Nitrogen. As a result, it can improve the reliability and efficiency of the surge protection system. This innovative anti-surge valve and control have been officially granted as a new patent in the US Patent and Trademark Office (USPTO) under Patent No. 11,209,842. The new surge control methodology will eliminate water hammering and potential pipeline damages without the use of external equipment to mitigate the surge.","PeriodicalId":153269,"journal":{"name":"Day 2 Thu, March 02, 2023","volume":"72 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127148397","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}
Frederic Robail, S. Sanyal, Ahmad Nazmi B M Noor Azudin, Kwi Yen Koh, Farahani Bt Hairon Nizar, Ummi Farah Mohamad Rosli
Multibillion barrels oil in-place carbonate reservoirs have their unique static and dynamic modelling challenges due to the nature of the reservoir with both vertical and lateral heterogeneities. The complex geological processes which took place both during and after the deposition, results in the heterogeneity, which are reflected in the reservoir characterization of these large-scale carbonate reservoirs. Capturing the geological facies variability in the reservoir description is thus one of the critical elements to ensure the model's validity, robustness, and forecasting ability. This case study exemplifies the use of a machine learning approach to tackle this subsurface complexity within a multidisciplinary integrated study to construct a field scale reservoir model for a large carbonate reservoir. The carbonate field has recently acquired additional core data in several newly drilled wells. These cores have been described by sedimentologists to define reservoir depositional facies and lithofacies. This geological description has been used by a machine learning algorithm to train the conventional triple combo logs to recognize the reservoir facies. The training of the facies definitions at the cored wells were also conditioned to the sequence stratigraphic correlation framework of the reservoir. Later these geological facies have been propagated using logs to more than 80 un-cored wells to provide facies predictions within a geological context. The result from the machine learning algorithm gives an excellent replication rate on the cored wells. It is also robust on the un-cored wells throughout the field. This robustness of the facies definitions has been verified using production / injection log survey (PLT / ILT), core CT-Scan and core descriptions. Firstly, for the cored wells, the production / injection zones identified by PLT surveys clearly correspond to the best reservoir facies. Secondly, in the un-cored wells, the best facies predicted by the machine learning algorithm correspond to the production / injection zones interpreted from the production and injection logging surveys (PLT survey) The predicted geological facies in both cored and un-cored wells and seismic inversion trends were used to condition the 3D distribution of the facies in the reservoir model. The use of machine learning for facies prediction has also helped to validate the underlying geological concept of an older good quality reservoir interval in certain areas of the field, which were not adequately sampled from the existing core data. In the future, the machine learning based reservoir models will be used to identify new infill locations where "best producing" facies are likely to be present.
{"title":"Machine Learning for Facies Distribution of Large Carbonate Reservoir Models- A Case Study","authors":"Frederic Robail, S. Sanyal, Ahmad Nazmi B M Noor Azudin, Kwi Yen Koh, Farahani Bt Hairon Nizar, Ummi Farah Mohamad Rosli","doi":"10.2523/iptc-22876-ms","DOIUrl":"https://doi.org/10.2523/iptc-22876-ms","url":null,"abstract":"\u0000 Multibillion barrels oil in-place carbonate reservoirs have their unique static and dynamic modelling challenges due to the nature of the reservoir with both vertical and lateral heterogeneities. The complex geological processes which took place both during and after the deposition, results in the heterogeneity, which are reflected in the reservoir characterization of these large-scale carbonate reservoirs. Capturing the geological facies variability in the reservoir description is thus one of the critical elements to ensure the model's validity, robustness, and forecasting ability.\u0000 This case study exemplifies the use of a machine learning approach to tackle this subsurface complexity within a multidisciplinary integrated study to construct a field scale reservoir model for a large carbonate reservoir.\u0000 The carbonate field has recently acquired additional core data in several newly drilled wells. These cores have been described by sedimentologists to define reservoir depositional facies and lithofacies. This geological description has been used by a machine learning algorithm to train the conventional triple combo logs to recognize the reservoir facies. The training of the facies definitions at the cored wells were also conditioned to the sequence stratigraphic correlation framework of the reservoir. Later these geological facies have been propagated using logs to more than 80 un-cored wells to provide facies predictions within a geological context.\u0000 The result from the machine learning algorithm gives an excellent replication rate on the cored wells. It is also robust on the un-cored wells throughout the field. This robustness of the facies definitions has been verified using production / injection log survey (PLT / ILT), core CT-Scan and core descriptions. Firstly, for the cored wells, the production / injection zones identified by PLT surveys clearly correspond to the best reservoir facies. Secondly, in the un-cored wells, the best facies predicted by the machine learning algorithm correspond to the production / injection zones interpreted from the production and injection logging surveys (PLT survey)\u0000 The predicted geological facies in both cored and un-cored wells and seismic inversion trends were used to condition the 3D distribution of the facies in the reservoir model. The use of machine learning for facies prediction has also helped to validate the underlying geological concept of an older good quality reservoir interval in certain areas of the field, which were not adequately sampled from the existing core data.\u0000 In the future, the machine learning based reservoir models will be used to identify new infill locations where \"best producing\" facies are likely to be present.","PeriodicalId":153269,"journal":{"name":"Day 2 Thu, March 02, 2023","volume":"67 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125337112","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}
The objective is to showcase the Abu Ali facility's commitment to protecting and preserving the Abu Ali biodiversity ecosystem. The project demonstrates a modern sustainable, circular, innovative and systemic approach to target the biodiversity threats in multi-dimensional aspects and transforms these threats into opportunities to improve the island's ecosystem. The island is important to Aramco's upstream operations because it houses an oil and gas production facility. The organization has determined its environmental goals from the corporate policies and vision to be as follows. Contribute to reaching the company's and the kingdom's vision for being a net zero-carbon operating facility by 2050 and 2060, respectively, by reducing and offsetting greenhouse gases’ impact on climate. Support the Saudi Green Initiative by planting mangroves and trees in the Abu Ali Island and seeking for sourcing out the mangrove seeds to other entities. Align and adapt with carbon circular economy (CCE) approaches in reusing/repairing/recycling wasted materials and resources turning them into valuable products. Protect, preserve and enhance the Abu Ali biodiversity area to create an integrated ecosystem for wildlife, marine life, and birds. Be recognized at the corporate, nationally, and internationally as a role model in environmental protection stewardship.
{"title":"Towards Sustainable Excellence & Biodiversity Protection in Upstream O & G Facility","authors":"Ali Alsinan, Khalilur Rehman, Ahmad Bakodah","doi":"10.2523/iptc-22902-ea","DOIUrl":"https://doi.org/10.2523/iptc-22902-ea","url":null,"abstract":"\u0000 \u0000 \u0000 The objective is to showcase the Abu Ali facility's commitment to protecting and preserving the Abu Ali biodiversity ecosystem. The project demonstrates a modern sustainable, circular, innovative and systemic approach to target the biodiversity threats in multi-dimensional aspects and transforms these threats into opportunities to improve the island's ecosystem. The island is important to Aramco's upstream operations because it houses an oil and gas production facility. The organization has determined its environmental goals from the corporate policies and vision to be as follows.\u0000 Contribute to reaching the company's and the kingdom's vision for being a net zero-carbon operating facility by 2050 and 2060, respectively, by reducing and offsetting greenhouse gases’ impact on climate. Support the Saudi Green Initiative by planting mangroves and trees in the Abu Ali Island and seeking for sourcing out the mangrove seeds to other entities. Align and adapt with carbon circular economy (CCE) approaches in reusing/repairing/recycling wasted materials and resources turning them into valuable products. Protect, preserve and enhance the Abu Ali biodiversity area to create an integrated ecosystem for wildlife, marine life, and birds. Be recognized at the corporate, nationally, and internationally as a role model in environmental protection stewardship.\u0000","PeriodicalId":153269,"journal":{"name":"Day 2 Thu, March 02, 2023","volume":"212 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122446152","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}
Chatawut Chanvanichskul, S. Punpruk, P. Phanichtraiphop, Passaworn Silakorn, Danai Taksanont, Sataporn Petchpong, Peerapong Taratapan, Sumet Sirivikrom, Rittichai Sukbanjongwatthana, Suthasinee Jinarakpong, Naruphorn Dararatana, Sukthida Sirithanawuthichai, A. Danthainum, Thitinun Sillapacharn
Oil and Gas Pipelines usually contain many contaminants from their long operational services in production. Prior to abandonment of a pipeline at the end of production, the environmental impact due to decommissioning must be assessed in order that the best pipeline decommissioning option, i.e. leave-in-place or by total removal, can be selected. In case of leave-in-place is selected, the decontamination of pipeline shall be performed so that the contaminant concentration is less than an acceptable level. PTTEP have developed own technologies to cover all scopes of decontamination works including contaminant measurement in pipeline since 2015. R&D were performed through technical survey, proof-of-concept, prototype testing, field testing to full deployment to 3 pipelines. The R&D were performed with academic/research institutes, contractors/manufacturers and government bodies. The R&D were divided into 3 main activities: Decontamination Methodology, Decontamination Chemical, Intelligent Sampling Pig. In 2021, PTTEP commenced the full decontamination using these own developments on three pipeline in the Gulf of Thailand to support the option selection of pipeline decommissioning. In this report, the summary of the overall pipeline decontamination process including the technology trial of all 3 R&D activities of three pipelines are described.
{"title":"The Success Case of the Decontamination of Production Sealines in the Gulf of Thailand","authors":"Chatawut Chanvanichskul, S. Punpruk, P. Phanichtraiphop, Passaworn Silakorn, Danai Taksanont, Sataporn Petchpong, Peerapong Taratapan, Sumet Sirivikrom, Rittichai Sukbanjongwatthana, Suthasinee Jinarakpong, Naruphorn Dararatana, Sukthida Sirithanawuthichai, A. Danthainum, Thitinun Sillapacharn","doi":"10.2523/iptc-22912-ea","DOIUrl":"https://doi.org/10.2523/iptc-22912-ea","url":null,"abstract":"\u0000 Oil and Gas Pipelines usually contain many contaminants from their long operational services in production. Prior to abandonment of a pipeline at the end of production, the environmental impact due to decommissioning must be assessed in order that the best pipeline decommissioning option, i.e. leave-in-place or by total removal, can be selected. In case of leave-in-place is selected, the decontamination of pipeline shall be performed so that the contaminant concentration is less than an acceptable level. PTTEP have developed own technologies to cover all scopes of decontamination works including contaminant measurement in pipeline since 2015. R&D were performed through technical survey, proof-of-concept, prototype testing, field testing to full deployment to 3 pipelines. The R&D were performed with academic/research institutes, contractors/manufacturers and government bodies. The R&D were divided into 3 main activities: Decontamination Methodology, Decontamination Chemical, Intelligent Sampling Pig.\u0000 In 2021, PTTEP commenced the full decontamination using these own developments on three pipeline in the Gulf of Thailand to support the option selection of pipeline decommissioning.\u0000 In this report, the summary of the overall pipeline decontamination process including the technology trial of all 3 R&D activities of three pipelines are described.","PeriodicalId":153269,"journal":{"name":"Day 2 Thu, March 02, 2023","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129595929","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}
Jakree Rungruang, Kolawat Swasdiphanich, N. Atibodhi, Jirat Juengsiripitak
To support the Company direction of GHG emission reduction in PTTEP operation, GBS, APEX and OMI have initiated fuel optimization to minimize fuel gas consumption. Over 80% of total fuel gas consumption is fed to Turbo Compressor to convert mechanical power to gas energy by compression system. To improve overall efficiency of fuel consumption, the whole gas compression process has been reviewed and analyzed. From preliminary review, there is a room to improve efficiency in part of gas cooling gas treatment process equipped with JT valve (Joule-Thomson, pressure reducing valve) that requires inlet pressure about 63-65 barg and outlet pressure of 55 barg to have cooling effect that decreases gas temperature from 45°C to 25°C. This cooling method takes huge energy from gas compressed in previous system. To improve overall process efficiency, the whole gas compression and cooling system was reviewed thoroughly. Consequently, it was found that the cooling margin of upstream equipment can compensate some cooling effect of JT valve leading to energy optimization of gas compression system without any additional modification and investment. After process tuning with the margin of Booster Compressor Discharge Cooler and Wet Gas / Gas Liquid Heat Exchanger upstream of JT valve, the required inlet pressure of JT valve can be reduced that leads to Booster Compressor discharge pressure declined from 64 barg to 61 barg while JT valve outlet temperature is still maintained at of 25°C as design condition without changing any other related operating condition of the systems before process tuning. The lower pressure of compressor discharge, the lesser fuel gas consumption is expected for energy transformation of compression system.
{"title":"Think Out of the Box – GHG Emission Reduction by Changing the Way We Had Operated Before","authors":"Jakree Rungruang, Kolawat Swasdiphanich, N. Atibodhi, Jirat Juengsiripitak","doi":"10.2523/iptc-22817-ea","DOIUrl":"https://doi.org/10.2523/iptc-22817-ea","url":null,"abstract":"\u0000 To support the Company direction of GHG emission reduction in PTTEP operation, GBS, APEX and OMI have initiated fuel optimization to minimize fuel gas consumption. Over 80% of total fuel gas consumption is fed to Turbo Compressor to convert mechanical power to gas energy by compression system. To improve overall efficiency of fuel consumption, the whole gas compression process has been reviewed and analyzed.\u0000 From preliminary review, there is a room to improve efficiency in part of gas cooling gas treatment process equipped with JT valve (Joule-Thomson, pressure reducing valve) that requires inlet pressure about 63-65 barg and outlet pressure of 55 barg to have cooling effect that decreases gas temperature from 45°C to 25°C. This cooling method takes huge energy from gas compressed in previous system. To improve overall process efficiency, the whole gas compression and cooling system was reviewed thoroughly. Consequently, it was found that the cooling margin of upstream equipment can compensate some cooling effect of JT valve leading to energy optimization of gas compression system without any additional modification and investment.\u0000 After process tuning with the margin of Booster Compressor Discharge Cooler and Wet Gas / Gas Liquid Heat Exchanger upstream of JT valve, the required inlet pressure of JT valve can be reduced that leads to Booster Compressor discharge pressure declined from 64 barg to 61 barg while JT valve outlet temperature is still maintained at of 25°C as design condition without changing any other related operating condition of the systems before process tuning. The lower pressure of compressor discharge, the lesser fuel gas consumption is expected for energy transformation of compression system.","PeriodicalId":153269,"journal":{"name":"Day 2 Thu, March 02, 2023","volume":"7 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128243791","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}
Anant Carasco, M. Khan, Azzril Zolhaili, Michiel Yntema, Christopher Leuranguer, Gregg Alexander
The plug and abandon (P&A) challenges of each well are known to be different. This paper narrates unique challenges faced during the abandonment of a land well which intersected multiple over-pressured reservoirs containing high concentration of H₂S and CO₂. Because zonal isolation was paramount for this project, section milling was selected to enable a rock-to-rock cement plug to restore 5 critical caprocks. Remediation of annular cement was complex because all production and intermediate casings were cemented to surface with 2 or 3 casings across the caprocks. Conventional methods would entail pilot milling the 7 inch production casing, exposing the A-annulus to enable section milling of the 9.625 inch intermediate casing for a cement plug across the caprock. This technique is time consuming and uncertain, which adds to the cost and complexity of the P&A operations. In response to these challenges, the operation was optimized utilizing both a standard section mill and a new High-Ratio Section Milling (HRSM) technology, which allows for milling windows through two casing strings. The HRSM is a combination of a high-ratio hydraulic section mill, achieving a 180% expansion ratio, and an expandable stabilizer. The orientation of the stabilizer is set to enable 6-point contact stabilization in the outer casing and helps to reduce dynamic shocks and vibrations. The HRSM is deployed after the inner 7-inch casing window has been milled for a length of approximately 140 ft. The expandable stabilizer in the system ensures that the section milling assembly can efficiently mill a 110 ft casing window in the 9.625 inch casing, through a 7 inch casing window. A high-ratio underreamer is utilized to clean the formation and enlarge the diameter to 13.5 inch to enable a rock-to-rock seal through two casing strings, without pilot milling the inner string from surface. Milling two casing strings is done in 5 stages. The inner casing window is initiated with a dedicated run using rapid cutout knives. This allows for deployment of "flush knives" while milling the inner window, reducing the risk of skimming the outer casing and enabling a single run of 139 ft casing milled. Following a clean out run with an under reamer, the new HRSM technology was then run and completed a 111 ft of 9.625-inch casing in one run, which was followed by 100 ft of hole enlargement by a high ratio underreamer to open the hole to 13.5 inches. All of the above stages were carried out in a single run and with good ROP. The cement job was completed and the objective of restoring the cap rock seal across two strings of casing was achieved, saving rig time and cost for the plug and abandonment operation. The development and successful deployment of HRSM technology provides a reliable solution to achieve a rock-to-rock cement plug in a dual-casing environment. During the execution phase various lessons were learnt and implemented as best practice, this included design changes of the HRSM t
{"title":"Dual Casing Section Milling Using High Ratio Section Milling Technology to Achieve Rock to Rock Zonal Isolation","authors":"Anant Carasco, M. Khan, Azzril Zolhaili, Michiel Yntema, Christopher Leuranguer, Gregg Alexander","doi":"10.2523/iptc-22890-ms","DOIUrl":"https://doi.org/10.2523/iptc-22890-ms","url":null,"abstract":"\u0000 The plug and abandon (P&A) challenges of each well are known to be different. This paper narrates unique challenges faced during the abandonment of a land well which intersected multiple over-pressured reservoirs containing high concentration of H₂S and CO₂. Because zonal isolation was paramount for this project, section milling was selected to enable a rock-to-rock cement plug to restore 5 critical caprocks. Remediation of annular cement was complex because all production and intermediate casings were cemented to surface with 2 or 3 casings across the caprocks. Conventional methods would entail pilot milling the 7 inch production casing, exposing the A-annulus to enable section milling of the 9.625 inch intermediate casing for a cement plug across the caprock. This technique is time consuming and uncertain, which adds to the cost and complexity of the P&A operations.\u0000 In response to these challenges, the operation was optimized utilizing both a standard section mill and a new High-Ratio Section Milling (HRSM) technology, which allows for milling windows through two casing strings. The HRSM is a combination of a high-ratio hydraulic section mill, achieving a 180% expansion ratio, and an expandable stabilizer. The orientation of the stabilizer is set to enable 6-point contact stabilization in the outer casing and helps to reduce dynamic shocks and vibrations. The HRSM is deployed after the inner 7-inch casing window has been milled for a length of approximately 140 ft. The expandable stabilizer in the system ensures that the section milling assembly can efficiently mill a 110 ft casing window in the 9.625 inch casing, through a 7 inch casing window. A high-ratio underreamer is utilized to clean the formation and enlarge the diameter to 13.5 inch to enable a rock-to-rock seal through two casing strings, without pilot milling the inner string from surface.\u0000 Milling two casing strings is done in 5 stages. The inner casing window is initiated with a dedicated run using rapid cutout knives. This allows for deployment of \"flush knives\" while milling the inner window, reducing the risk of skimming the outer casing and enabling a single run of 139 ft casing milled. Following a clean out run with an under reamer, the new HRSM technology was then run and completed a 111 ft of 9.625-inch casing in one run, which was followed by 100 ft of hole enlargement by a high ratio underreamer to open the hole to 13.5 inches. All of the above stages were carried out in a single run and with good ROP. The cement job was completed and the objective of restoring the cap rock seal across two strings of casing was achieved, saving rig time and cost for the plug and abandonment operation.\u0000 The development and successful deployment of HRSM technology provides a reliable solution to achieve a rock-to-rock cement plug in a dual-casing environment. During the execution phase various lessons were learnt and implemented as best practice, this included design changes of the HRSM t","PeriodicalId":153269,"journal":{"name":"Day 2 Thu, March 02, 2023","volume":"14 3 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123810303","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}
The purpose of the paper is to illustrate the development of the innovative system of continuous circulation drilling. With an important contribution of a cameras system an Artificial Intelligence, the drilling operation are much more accurate and fully automated. The presence of personnel on the drillfloor is not required and controlling it takes place remotely from inside the driller cabin. The automated system is composed of a: Clamp, Trolley, Mud Diverter Manifold, Vision System, HMI and PLC Control Skid. The trolley and clamp are remotely controlled from the driller cabin. With the aid of the vision system, the driller is able to align the clamp with the external valve on the sub and move forwards or backwards as needed. With an angle of +/- 10 ° to the right and left, the alignment can take place in the three directions of the space.The software is set up to minimize human and system error. The CCS technology has evolved to be used on the last generation drilling rigs. The implementation of a fully automated system that makes use of artificial intelligence allows remote control and creates the possibility of carrying out operations safely without operators on the drilling floor. The technology allows operations to be carried out continuously and in compliance with safety standards. The cameras allow to operate in the most critical conditions, using a lighting system with a setting that has been tested and set in the worst operating conditions. The valve detection and alignment of the system to the sub allows to start the continuous circulation. The use of AI allows for drastic enhancement in drilling efficiency and safety standards reducing the number of humans needed inputs. The human-machine interaction represents a competitive advantage over traditional systems. The automation of drilling improves the way to drill wells, producing benefits in terms of optimizing the critical analytical decision and, more generally, returns significant operative savings. Another key benefit of AI-infused drilling is safety: less people involved in operations, with an increased skill set. The paper's goal is to show the world a new frontier of drilling.
{"title":"Improvement of Safety with Ai Applied on a Rig Continuous Circulation System","authors":"Vincenzo Michele Mamuscia, A. Calderoni","doi":"10.2523/iptc-23101-ea","DOIUrl":"https://doi.org/10.2523/iptc-23101-ea","url":null,"abstract":"\u0000 The purpose of the paper is to illustrate the development of the innovative system of continuous circulation drilling. With an important contribution of a cameras system an Artificial Intelligence, the drilling operation are much more accurate and fully automated. The presence of personnel on the drillfloor is not required and controlling it takes place remotely from inside the driller cabin.\u0000 The automated system is composed of a: Clamp, Trolley, Mud Diverter Manifold, Vision System, HMI and PLC Control Skid. The trolley and clamp are remotely controlled from the driller cabin. With the aid of the vision system, the driller is able to align the clamp with the external valve on the sub and move forwards or backwards as needed. With an angle of +/- 10 ° to the right and left, the alignment can take place in the three directions of the space.The software is set up to minimize human and system error.\u0000 The CCS technology has evolved to be used on the last generation drilling rigs. The implementation of a fully automated system that makes use of artificial intelligence allows remote control and creates the possibility of carrying out operations safely without operators on the drilling floor. The technology allows operations to be carried out continuously and in compliance with safety standards. The cameras allow to operate in the most critical conditions, using a lighting system with a setting that has been tested and set in the worst operating conditions. The valve detection and alignment of the system to the sub allows to start the continuous circulation. The use of AI allows for drastic enhancement in drilling efficiency and safety standards reducing the number of humans needed inputs. The human-machine interaction represents a competitive advantage over traditional systems.\u0000 The automation of drilling improves the way to drill wells, producing benefits in terms of optimizing the critical analytical decision and, more generally, returns significant operative savings. Another key benefit of AI-infused drilling is safety: less people involved in operations, with an increased skill set. The paper's goal is to show the world a new frontier of drilling.","PeriodicalId":153269,"journal":{"name":"Day 2 Thu, March 02, 2023","volume":"601 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123196106","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}
Intelligent automated industrial process control requires a higher level of systems integration and connectedness than what has traditionally been the case. With such development comes increased risk of cyber-attack for Operational Technology (OT) systems such as Industrial Control Systems (ICS). For ICS, cyber-attacks can have significant consequences also in the physical world, with potentially catastrophic consequences, as experienced in the Colonial Pipeline and the Ukraine Power Grid attacks. Physical risk to the work environment, the product, and surroundings should therefore be accounted for in cybersecurity solutions for ICS. For this purpose, models and methods are required that consider the function of the whole Cyber-Physical System (CPS) not just the ICS, with the capability of detecting and correlating observations across the layers of system control, including the physical process being controlled. To achieve this, a context-based detection approach that can model the CPS and combine this with a process-aware risk analysis for attack response is proposed. The approach also needs to be adaptable (intelligent) to account for the process dynamics and the evolving cyber-attack threats. For this purpose, diagnostic models adapted to the industrial process should be applied together with situational awareness monitoring and cyber-attack detection tools, such as ICS Intrusion Detection Systems (IDS). The capability of the ICS IDS therefore needs to be extended to cover both Information Technology (IT) and OT parts of the ICS and include an understanding of the physical system and process as a knowledge basis, fed by process sensor and instrumentation data. These diagnostic models must cover the whole CPS in the risk analysis to provide aid in the attack response decision making. To achieve this, the models need to combine the physical characteristics of the process with the characteristics of the other system layers. Based on studies in a drilling control system environment, results indicate that existing tools can be used to detect and discern between different types of cyber-attack on Cyber-Physical Systems (CPS). This indicates feasibility with respect to monitoring of the OT and IT part of the system for building risk-based cybersecurity solutions. The challenge and novel part are to extend IT and OT systems cyber detection with automated evaluation of the resulting process risk taking physical process information into account, to make response decisions not only based on potential digital consequences but also consequences for the process and physical world.
{"title":"Intelligent Risk Based Cybersecurity Protection for Industrial Systems Control - A Feasibility Study","authors":"S. Houmb, F. Iversen, Robert Ewald, Einar Færaas","doi":"10.2523/iptc-22795-ms","DOIUrl":"https://doi.org/10.2523/iptc-22795-ms","url":null,"abstract":"\u0000 Intelligent automated industrial process control requires a higher level of systems integration and connectedness than what has traditionally been the case. With such development comes increased risk of cyber-attack for Operational Technology (OT) systems such as Industrial Control Systems (ICS). For ICS, cyber-attacks can have significant consequences also in the physical world, with potentially catastrophic consequences, as experienced in the Colonial Pipeline and the Ukraine Power Grid attacks. Physical risk to the work environment, the product, and surroundings should therefore be accounted for in cybersecurity solutions for ICS.\u0000 For this purpose, models and methods are required that consider the function of the whole Cyber-Physical System (CPS) not just the ICS, with the capability of detecting and correlating observations across the layers of system control, including the physical process being controlled. To achieve this, a context-based detection approach that can model the CPS and combine this with a process-aware risk analysis for attack response is proposed. The approach also needs to be adaptable (intelligent) to account for the process dynamics and the evolving cyber-attack threats. For this purpose, diagnostic models adapted to the industrial process should be applied together with situational awareness monitoring and cyber-attack detection tools, such as ICS Intrusion Detection Systems (IDS). The capability of the ICS IDS therefore needs to be extended to cover both Information Technology (IT) and OT parts of the ICS and include an understanding of the physical system and process as a knowledge basis, fed by process sensor and instrumentation data. These diagnostic models must cover the whole CPS in the risk analysis to provide aid in the attack response decision making. To achieve this, the models need to combine the physical characteristics of the process with the characteristics of the other system layers.\u0000 Based on studies in a drilling control system environment, results indicate that existing tools can be used to detect and discern between different types of cyber-attack on Cyber-Physical Systems (CPS). This indicates feasibility with respect to monitoring of the OT and IT part of the system for building risk-based cybersecurity solutions. The challenge and novel part are to extend IT and OT systems cyber detection with automated evaluation of the resulting process risk taking physical process information into account, to make response decisions not only based on potential digital consequences but also consequences for the process and physical world.","PeriodicalId":153269,"journal":{"name":"Day 2 Thu, March 02, 2023","volume":"152 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123359401","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}
Two Riser hoses attached with FSO2 (Floating, Storage & Offloading) has estimated service life (9.3 years). The next replacement is required before July 2022. Thus, in June 2022 Project team had planned to disconnect and reinstall two newly riser hoses with approach to comingle production stream enable to continue production without any shutdown. The overall execution plan has learnt best practices from previous operation since 2013. For 15 days offshore execution, collaboration between Project team, Operation & Maintenance, Marine team and specialized contractor is essential. The offshore execution began with preparation steps which include tank offloading, heading control system, pre-installation visual survey, before comingling to operate one riser hose and flushing another. Then, the 5 days operation per hose to disconnect, replace the newly hose. After leak test and hydrotesting all connections was performed, Production team will switch the production via this new hose and repeat similar replacement steps with another hose. On technical aspects, the riser hose replacement may consider not a complicated task. Although advance preparation prior commencing offshore installation in conjunction with experiences contractor are critical and important. Collaboration with various stakeholders requires full attention to address those concerned areas with mitigation and measures especially on HSE aspects resulted from risk assessment and several workshops. Strategic approach to perform the riser hoses replacement without interrupting the production is a challenge. Applying comingle strategy requires effort to breakdown related activities and sequential analysis to ensure all the execution will be smooth without jeopardizing the HSE issues. Also, during the contractor selection stage Project team had selected national qualified contractor. It turns out that national contractor also has similar capability to manage and deliver this scale of project with very acceptable quality but competitive price. Even this is not PTTEP first riser hoses replacement project though the Project team would like to remark great achievement which could only arise from effective teamwork, good collaboration among all relevant stakeholders and benchmarked best practices from our expertise and learned from previous experiences. In addition, it is worth to mention that the offshore execution was performed safely without interrupting the environment and the ongoing production.
{"title":"2022 FSO2 Riser Hoses Replacement Project (Bongkot Asset)","authors":"Navakorn Sayatanan, Sataporn Petchpong, Thamonwan Kittithornkul, Juthaporn Charoenphol, Apichart Whungkhunnatham, Santi Thuengsripan, Somchai Ploiriang, Phitsanusak Insuk, Nopharut Laopornpichayanuwat, Manisa Sangwattanachai, Mahapon Toungsetwut, Danai Srijunngam, Manit Aimcharoenchaiyakul, Ekkalak Somroop","doi":"10.2523/iptc-22740-ms","DOIUrl":"https://doi.org/10.2523/iptc-22740-ms","url":null,"abstract":"\u0000 Two Riser hoses attached with FSO2 (Floating, Storage & Offloading) has estimated service life (9.3 years). The next replacement is required before July 2022. Thus, in June 2022 Project team had planned to disconnect and reinstall two newly riser hoses with approach to comingle production stream enable to continue production without any shutdown.\u0000 The overall execution plan has learnt best practices from previous operation since 2013. For 15 days offshore execution, collaboration between Project team, Operation & Maintenance, Marine team and specialized contractor is essential. The offshore execution began with preparation steps which include tank offloading, heading control system, pre-installation visual survey, before comingling to operate one riser hose and flushing another. Then, the 5 days operation per hose to disconnect, replace the newly hose. After leak test and hydrotesting all connections was performed, Production team will switch the production via this new hose and repeat similar replacement steps with another hose.\u0000 On technical aspects, the riser hose replacement may consider not a complicated task. Although advance preparation prior commencing offshore installation in conjunction with experiences contractor are critical and important. Collaboration with various stakeholders requires full attention to address those concerned areas with mitigation and measures especially on HSE aspects resulted from risk assessment and several workshops.\u0000 Strategic approach to perform the riser hoses replacement without interrupting the production is a challenge. Applying comingle strategy requires effort to breakdown related activities and sequential analysis to ensure all the execution will be smooth without jeopardizing the HSE issues. Also, during the contractor selection stage Project team had selected national qualified contractor. It turns out that national contractor also has similar capability to manage and deliver this scale of project with very acceptable quality but competitive price.\u0000 Even this is not PTTEP first riser hoses replacement project though the Project team would like to remark great achievement which could only arise from effective teamwork, good collaboration among all relevant stakeholders and benchmarked best practices from our expertise and learned from previous experiences. In addition, it is worth to mention that the offshore execution was performed safely without interrupting the environment and the ongoing production.","PeriodicalId":153269,"journal":{"name":"Day 2 Thu, March 02, 2023","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131285154","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}
The main mechanism of waterflooding and enhanced oil recovery (EOR) is oil displacement by injected fluid; however, complexity in the geological system, limited understanding of interwell connectivity, vertical heterogeneity, and lack of injection and production controls lead to lower-than-expected flood performance. This study is aimed to assess and optimize the ongoing waterflood and polymer flooding performance in a mature S1 oil field in Thailand. The capacitance resistance model (CRM) is a physics-based reservoir model that derives interwell connectivity and reservoir properties solely from the input of production, injection, and pressure data. In this study, the rigorous workflow of CRM model coupled with fractional flow model was built by using Python language to dynamically perform the reservoir analysis focusing on the polymer pilot and mature waterflood areas. The reservoir connectivity map and reservoir properties were obtained from the CRM model matching, and the flood optimization plan was the output after coupling those two models. The CRM model provides good fittings of well production rates in case there is sufficient production data and the derived interwell connectivity is in good agreement with the interwell tracer results, the regional sedimentary supply direction, and waterflood analysis by reservoir engineers. The input of bottomhole pressure data from electric submersible pump (ESP) sensors can enhance the quality of CRM fittings, especially when reservoir is in the under-injection state. For the optimization study, well injection rates were adjusted with the objective function to maximize oil reserves, and the results signified a total incremental oil gain of 1 MMSTB approximately. The recommended waterflood optimization plan was implemented and is being evaluated in the field. The integrated CRM workflow could replace the 3D-conventional reservoir simulation model where it may contain high uncertainty of geological structures and characteristics. The CRM also enables the intensive waterflood and EOR assessment as well as flood performance optimization. This application would be a key to ensuring the success of the waterflood and EOR journey.
{"title":"Advancement in Waterflood and EOR Performance Assessment and Optimization with Capacitance-Resistance Model in the Largest Oil Field, Thailand","authors":"R. Laochamroonvorapongse","doi":"10.2523/iptc-22862-ms","DOIUrl":"https://doi.org/10.2523/iptc-22862-ms","url":null,"abstract":"\u0000 The main mechanism of waterflooding and enhanced oil recovery (EOR) is oil displacement by injected fluid; however, complexity in the geological system, limited understanding of interwell connectivity, vertical heterogeneity, and lack of injection and production controls lead to lower-than-expected flood performance. This study is aimed to assess and optimize the ongoing waterflood and polymer flooding performance in a mature S1 oil field in Thailand.\u0000 The capacitance resistance model (CRM) is a physics-based reservoir model that derives interwell connectivity and reservoir properties solely from the input of production, injection, and pressure data. In this study, the rigorous workflow of CRM model coupled with fractional flow model was built by using Python language to dynamically perform the reservoir analysis focusing on the polymer pilot and mature waterflood areas. The reservoir connectivity map and reservoir properties were obtained from the CRM model matching, and the flood optimization plan was the output after coupling those two models.\u0000 The CRM model provides good fittings of well production rates in case there is sufficient production data and the derived interwell connectivity is in good agreement with the interwell tracer results, the regional sedimentary supply direction, and waterflood analysis by reservoir engineers. The input of bottomhole pressure data from electric submersible pump (ESP) sensors can enhance the quality of CRM fittings, especially when reservoir is in the under-injection state. For the optimization study, well injection rates were adjusted with the objective function to maximize oil reserves, and the results signified a total incremental oil gain of 1 MMSTB approximately. The recommended waterflood optimization plan was implemented and is being evaluated in the field.\u0000 The integrated CRM workflow could replace the 3D-conventional reservoir simulation model where it may contain high uncertainty of geological structures and characteristics. The CRM also enables the intensive waterflood and EOR assessment as well as flood performance optimization. This application would be a key to ensuring the success of the waterflood and EOR journey.","PeriodicalId":153269,"journal":{"name":"Day 2 Thu, March 02, 2023","volume":"25 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-02-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132012788","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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