With China committing to achieve carbon neutrality before 2060, the operator has set ambitious targets for minimizing carbon emissions from its oil and gas operations. Two extensive offshore oil fields – QHD32-6 and CDF 11-1 oil fields have been modified to transform its power solution from offshore generation to power from shore (PFS) to reduce carbon emission, improve offshore energy efficiency etc. The two fields comprise 25 production platforms, 2 FPSO with 21 crude oil generators and 9 gas turbine generators. The total peak power demand is about 200MW. Both QHD32-6 and CDF 11-1 oil fields have established their own offshore micro power grid by interlinking centralized offshore generation platforms via 35kV and 10kV submarine cables. This paper first reviews the company strategic factors as well as the national regulatory drivers behind the decision to pursue whole-scale electrification of two super complex offshore oil fields. It then explores technology challenges and solutions by means of a high voltage AC PFS such as tie-in point selection, reactive compensation considerations, key economic criteria such as operation and energy costs, and asset depreciation etc. Considering the consequences of production loss due to power outage, stringent reliability requirements were adopted. A high-speed transfer combine with a 62.3km 110kV interconnecting submarine cable between QHD32-6 and CFD11-1 offshore substations is first introduced in offshore PFS installations. Detailed configuration and its power supply continuity benefit will be discussed. Finally, major cost reduction measures such as unman and digitalization design of 220kV PFS substation are summarized, with lessons learned in a successful development of extensive on-stream oil fields electrification transformation. This electrification transformation is expected to reduce about a total 2.52 million tons of CO2 and 0.067 million tons of NOx emissions, save 2.17 billion cubic meters of fuel gas and 1.13 million tons of standard coals. In September 2021, QHD32-6 and CFD11-1 offshore oil fields have been completed the transformation and back into production. Although on account of a total 132km submarine cables and 200MW power demand, high voltage D.C. is traditionally the first choice, this paper demonstrates high voltage A.C. can be flexibly utilized for long distance large power demand by careful design. While for many upcoming offshore projects, PFS solutions have become attractive in an effort to reduce environmental footprint, this paper presents an on-stream offshore oil fields PFS transformation, extra considerations need to be addressed. The high-speed transfer solution is first used in PFS engineering that can limit a power switching time to milliseconds, exploring a new way to significantly improve power supply continuity with limited investment. Another new information is the unmanned and intelligent design of substations to increase asset adaptability, maintain system relia
{"title":"Electrification Transformation from Offshore Power Grid to Power from Shore, a Case Study to Minimize Carbon Emissions for Two Extensive Offshore Oil Fields","authors":"Yiru Hu, H. Zhang, Yinfeng Qiu","doi":"10.4043/31550-ms","DOIUrl":"https://doi.org/10.4043/31550-ms","url":null,"abstract":"\u0000 With China committing to achieve carbon neutrality before 2060, the operator has set ambitious targets for minimizing carbon emissions from its oil and gas operations. Two extensive offshore oil fields – QHD32-6 and CDF 11-1 oil fields have been modified to transform its power solution from offshore generation to power from shore (PFS) to reduce carbon emission, improve offshore energy efficiency etc. The two fields comprise 25 production platforms, 2 FPSO with 21 crude oil generators and 9 gas turbine generators. The total peak power demand is about 200MW. Both QHD32-6 and CDF 11-1 oil fields have established their own offshore micro power grid by interlinking centralized offshore generation platforms via 35kV and 10kV submarine cables.\u0000 This paper first reviews the company strategic factors as well as the national regulatory drivers behind the decision to pursue whole-scale electrification of two super complex offshore oil fields. It then explores technology challenges and solutions by means of a high voltage AC PFS such as tie-in point selection, reactive compensation considerations, key economic criteria such as operation and energy costs, and asset depreciation etc. Considering the consequences of production loss due to power outage, stringent reliability requirements were adopted. A high-speed transfer combine with a 62.3km 110kV interconnecting submarine cable between QHD32-6 and CFD11-1 offshore substations is first introduced in offshore PFS installations. Detailed configuration and its power supply continuity benefit will be discussed. Finally, major cost reduction measures such as unman and digitalization design of 220kV PFS substation are summarized, with lessons learned in a successful development of extensive on-stream oil fields electrification transformation.\u0000 This electrification transformation is expected to reduce about a total 2.52 million tons of CO2 and 0.067 million tons of NOx emissions, save 2.17 billion cubic meters of fuel gas and 1.13 million tons of standard coals. In September 2021, QHD32-6 and CFD11-1 offshore oil fields have been completed the transformation and back into production. Although on account of a total 132km submarine cables and 200MW power demand, high voltage D.C. is traditionally the first choice, this paper demonstrates high voltage A.C. can be flexibly utilized for long distance large power demand by careful design.\u0000 While for many upcoming offshore projects, PFS solutions have become attractive in an effort to reduce environmental footprint, this paper presents an on-stream offshore oil fields PFS transformation, extra considerations need to be addressed. The high-speed transfer solution is first used in PFS engineering that can limit a power switching time to milliseconds, exploring a new way to significantly improve power supply continuity with limited investment. Another new information is the unmanned and intelligent design of substations to increase asset adaptability, maintain system relia","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"114 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87965830","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}
Nurul Nadia Ezzatty Abu Bakar, M. Hod, M. A. Abitalhah, A. F. Omar, Hazlan Abdul Hakim
This paper will discuss the key focus areas in successfully delivering a slim well design as a Proof Of Concept (POC) for marginal fields and well cost optimization. Well Tall-A is a Near Field Exploration (NFE) well targeting marginal reservoir which utilize the slim well concept; a 2-hole section well with 9-5/8" as the conductor. For a successful well execution, three (3) key focus areas were identified which are successful operation of 9-5/8" Casing While Drilling (CWD) to section TD, sustainability of 9-5/8" casing as conductor for the whole well life cycle and achievement of well objectives. Tall-A recorded the longest and successful 9-5/8" CWD Level 2 (non-directional) for Asia Pacific with 1168m drilled footage as of year 2020. Lessons learnt from previous PCSB 9-5/8" CWD operation were incorporated for casing bit selection hence a heavy-set casing bit (8 bladed) which has been proven in drilling long hole interval in the Middle East (>1000m) was utilized. Continuous monitoring during execution is essential in ensuring the casing is set at the desired setting depth. Sustainability of the 9-5/8" casing as conductor for the whole well life cycle is critical for a slim well design concept. Several studies and extensive discussions between multiple parties has been incorporated to enable utilization of the 9-5/8" as conductor with required sufficient tension to sustain the exploration well lifecycle. A conductor study was performed which incorporated the Metocean data, rig data and connection Stress Concentration Fatigue (SCF) to qualify the 9-5/8" as conductor. To meet the primary and secondary targets; the 8-1/2" hole needs to be kicked-off early and build up to maximum 44 deg before maintain tangent to final TD at 2752m MDDF. Due to the long open hole (1475m) and well inclination within the avalanche hole cleaning regime (30 to 60 deg), the well is prone to hole cleaning problem and wellbore instability. Hence, it is critical to have good drilling practices and precise mud weight selection to ensure no hole problem encountered. The well was successfully drilled to TD, completed the well testing and P&A. In summary, well Tall-A successfully maneuvered all challenges to deliver the well safely that resulted in Best In Class (BIC) performance. The slim well design concept has been proven achievable and serve as base design for future marginal wells.
{"title":"Successful Delivery of Slim Well Design Concept for Future Marginal Fields","authors":"Nurul Nadia Ezzatty Abu Bakar, M. Hod, M. A. Abitalhah, A. F. Omar, Hazlan Abdul Hakim","doi":"10.4043/31357-ms","DOIUrl":"https://doi.org/10.4043/31357-ms","url":null,"abstract":"\u0000 This paper will discuss the key focus areas in successfully delivering a slim well design as a Proof Of Concept (POC) for marginal fields and well cost optimization.\u0000 Well Tall-A is a Near Field Exploration (NFE) well targeting marginal reservoir which utilize the slim well concept; a 2-hole section well with 9-5/8\" as the conductor. For a successful well execution, three (3) key focus areas were identified which are successful operation of 9-5/8\" Casing While Drilling (CWD) to section TD, sustainability of 9-5/8\" casing as conductor for the whole well life cycle and achievement of well objectives.\u0000 Tall-A recorded the longest and successful 9-5/8\" CWD Level 2 (non-directional) for Asia Pacific with 1168m drilled footage as of year 2020. Lessons learnt from previous PCSB 9-5/8\" CWD operation were incorporated for casing bit selection hence a heavy-set casing bit (8 bladed) which has been proven in drilling long hole interval in the Middle East (>1000m) was utilized. Continuous monitoring during execution is essential in ensuring the casing is set at the desired setting depth. Sustainability of the 9-5/8\" casing as conductor for the whole well life cycle is critical for a slim well design concept. Several studies and extensive discussions between multiple parties has been incorporated to enable utilization of the 9-5/8\" as conductor with required sufficient tension to sustain the exploration well lifecycle. A conductor study was performed which incorporated the Metocean data, rig data and connection Stress Concentration Fatigue (SCF) to qualify the 9-5/8\" as conductor. To meet the primary and secondary targets; the 8-1/2\" hole needs to be kicked-off early and build up to maximum 44 deg before maintain tangent to final TD at 2752m MDDF. Due to the long open hole (1475m) and well inclination within the avalanche hole cleaning regime (30 to 60 deg), the well is prone to hole cleaning problem and wellbore instability. Hence, it is critical to have good drilling practices and precise mud weight selection to ensure no hole problem encountered. The well was successfully drilled to TD, completed the well testing and P&A.\u0000 In summary, well Tall-A successfully maneuvered all challenges to deliver the well safely that resulted in Best In Class (BIC) performance. The slim well design concept has been proven achievable and serve as base design for future marginal wells.","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"70 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84412922","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}
Azwan Azim Azihar, Maziah Abu Mukhtar, Shahril Yang, M. Z. A Razak, A. Z. A Rajab, M. A. Tumiran
This paper covers the strategy that led to successful execution of Plug and Abandonment (P&A) campaign. This paper also shares the best practices implementation, and challenges in completion of the biggest plug and abandonment campaign at Alpha Platform in Peninsular Malaysia. Among the challenges are aging wells with numerous integrity issues, well sequence selection and prioritization, monsoon season, stakeholder management as well as piloting new technology applications. In the last 5 years, there are over 50 wells have been successfully abandoned in Malaysia water. The generic abandonment project management framework consists of Initiation Stage, Concept Selection, Scope Definition, Execution, and Post Execution; Close Out. The scope for this paper will detail out the levels for abandonment planning. Screening and clustering, fit-for-purpose strategy, novel technology, innovative contracting strategy are among the pillars in abandonment planning and execution. Effective tools and matrix have been introduced to evaluate the wells candidates. Execution phase is narrowed down to several approaches and best practices that have been implemented to successfully complete all wells at Alpha Platform. The approaches have been customized to safely abandon wells with sustained annulus pressure (SAP) in compliance with the country's regulations. In-depth well study and aggressively piloting new technology are among the keys to tackle numerous well integrity issue in 40 years old wells e.g shallow gas, casing leak, wellhead, and Christmas tree leak. Vigilant logistic management and integrated contract approach also play important roles in reducing the risk and liability to the operator and at the same time developing local players’ capability. The strategy and best practices in completing plug and abandonment of Alpha Platform should be replicated by P&A industry to manage the similar issue in other projects. Integrated and fit-for-purpose abandonment approach act as the foundation to model invaluable high-quality planning, forecasting and Value Creation Plan for P&A project portfolio. This paper will be useful in P&A industry where a lot of lessons learned to be shared in the biggest campaign in Malaysia.
{"title":"Biggest Wells Plug and Abandonment Campaign – Effective Management & Best Practices Implementation","authors":"Azwan Azim Azihar, Maziah Abu Mukhtar, Shahril Yang, M. Z. A Razak, A. Z. A Rajab, M. A. Tumiran","doi":"10.4043/31403-ms","DOIUrl":"https://doi.org/10.4043/31403-ms","url":null,"abstract":"\u0000 This paper covers the strategy that led to successful execution of Plug and Abandonment (P&A) campaign. This paper also shares the best practices implementation, and challenges in completion of the biggest plug and abandonment campaign at Alpha Platform in Peninsular Malaysia. Among the challenges are aging wells with numerous integrity issues, well sequence selection and prioritization, monsoon season, stakeholder management as well as piloting new technology applications.\u0000 In the last 5 years, there are over 50 wells have been successfully abandoned in Malaysia water. The generic abandonment project management framework consists of Initiation Stage, Concept Selection, Scope Definition, Execution, and Post Execution; Close Out. The scope for this paper will detail out the levels for abandonment planning. Screening and clustering, fit-for-purpose strategy, novel technology, innovative contracting strategy are among the pillars in abandonment planning and execution. Effective tools and matrix have been introduced to evaluate the wells candidates. Execution phase is narrowed down to several approaches and best practices that have been implemented to successfully complete all wells at Alpha Platform. The approaches have been customized to safely abandon wells with sustained annulus pressure (SAP) in compliance with the country's regulations. In-depth well study and aggressively piloting new technology are among the keys to tackle numerous well integrity issue in 40 years old wells e.g shallow gas, casing leak, wellhead, and Christmas tree leak. Vigilant logistic management and integrated contract approach also play important roles in reducing the risk and liability to the operator and at the same time developing local players’ capability.\u0000 The strategy and best practices in completing plug and abandonment of Alpha Platform should be replicated by P&A industry to manage the similar issue in other projects. Integrated and fit-for-purpose abandonment approach act as the foundation to model invaluable high-quality planning, forecasting and Value Creation Plan for P&A project portfolio. This paper will be useful in P&A industry where a lot of lessons learned to be shared in the biggest campaign in Malaysia.","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"18 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73654072","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}
N. Atibodhi, Supha-Kitti Dhadachaipathomphong, F. Nazir, Nathachok Namwong
PTTEP's natural gas fields in Gulf of Thailand, has encountered losses in Condensate yield due to suboptimal operating conditions as variation in feed compositions occurs when production line up changes. As a result of this suboptimal operation, some light Condensate is lost into gas phase resulting in lower overall profitability. As part of company's Digital Transformation initiatives, a Condensate Stabilizer Optimization (CSO) solution has been implemented to minimize or eliminate these losses. The objective of CSO is to provide real-time recommended operating conditions to maximize condensate production while maintaining sale condensate specification using optimization technology that considers all relevant condensate stabilization process parameters. The CSO solution leverages Multivariable Predictive Control or Model Predictive Control (MPC) technology and communicates the obtained results to offshore teams via an online web user interface. Besides the dynamic models and MPC technology, the solution also includes an important component of the CSO solution which is the web based online dashboards as they are the key to communicate between the solution and the users. The dashboards include the following key features: – Key operating parameters of Condensate Stabilizer Units including Controlled, Manipulated, and Disturbance Variables – Recommended optimal values of Manipulated Variables to achieve maximum condensate production – Difference between actual vs predicted RVP. This is to visualize current model accuracy – Captured Benefit As of December 2021, the CSO solution has been fully utilized for 5 months, i.e. Go-Live since August 2021. During this period, it has successfully delivered not only safe operating window but also benefits which adds up to 1.49 MUSD/year. As the benefits of the solution have been proven, a plan to proceed with Phase 2 of this project, in which the CSO solution will be integrated with the Distributed Control System (DCS) allowing MPC Controller to automatically adjust process parameters to achieve the most optimal conditions, has been set. Apart from process optimization, the CSO solution can be used to evaluate operating scenarios based on given simulated process parameters, thus becoming a true "Digital Twin" of the Condensate Stabilizer that can replicate its operation at different operating conditions.
{"title":"Digital Transformation for the Gulf of Thailand's Assets Condensate Stabilizer Real-Time Optimization","authors":"N. Atibodhi, Supha-Kitti Dhadachaipathomphong, F. Nazir, Nathachok Namwong","doi":"10.4043/31363-ms","DOIUrl":"https://doi.org/10.4043/31363-ms","url":null,"abstract":"\u0000 PTTEP's natural gas fields in Gulf of Thailand, has encountered losses in Condensate yield due to suboptimal operating conditions as variation in feed compositions occurs when production line up changes. As a result of this suboptimal operation, some light Condensate is lost into gas phase resulting in lower overall profitability.\u0000 As part of company's Digital Transformation initiatives, a Condensate Stabilizer Optimization (CSO) solution has been implemented to minimize or eliminate these losses. The objective of CSO is to provide real-time recommended operating conditions to maximize condensate production while maintaining sale condensate specification using optimization technology that considers all relevant condensate stabilization process parameters.\u0000 The CSO solution leverages Multivariable Predictive Control or Model Predictive Control (MPC) technology and communicates the obtained results to offshore teams via an online web user interface.\u0000 Besides the dynamic models and MPC technology, the solution also includes an important component of the CSO solution which is the web based online dashboards as they are the key to communicate between the solution and the users. The dashboards include the following key features:\u0000 – Key operating parameters of Condensate Stabilizer Units including Controlled, Manipulated, and Disturbance Variables – Recommended optimal values of Manipulated Variables to achieve maximum condensate production – Difference between actual vs predicted RVP. This is to visualize current model accuracy – Captured Benefit\u0000 As of December 2021, the CSO solution has been fully utilized for 5 months, i.e. Go-Live since August 2021. During this period, it has successfully delivered not only safe operating window but also benefits which adds up to 1.49 MUSD/year. As the benefits of the solution have been proven, a plan to proceed with Phase 2 of this project, in which the CSO solution will be integrated with the Distributed Control System (DCS) allowing MPC Controller to automatically adjust process parameters to achieve the most optimal conditions, has been set.\u0000 Apart from process optimization, the CSO solution can be used to evaluate operating scenarios based on given simulated process parameters, thus becoming a true \"Digital Twin\" of the Condensate Stabilizer that can replicate its operation at different operating conditions.","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"108 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79209597","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}
Thinesh Shakkti Arul Rajoo, K. Elraies, U. Z. Husna, Juhairi Aris Muhamad Shuhili, Mohd Afandi Abu Bakar, Hazliza Haron, Ismail Mohd Saaid, J. Lee, M. N. Mohamad Ibrahim, S. B. Gogoi, A. Saeedi
One of the emerging areas in combatting environmental issue like global warming is carbon capture and storage (CCS) entices a solution by not limiting output of any operation. Carbon capture storage refers to the process of capturing or gathering carbon dioxide released into the atmosphere from various activities and injecting the captured gas underground (aquifer). CCS can be divided into 3 main stages namely capturing, transportation and storage. The carbon dioxide will be captured from a source, being transported and sequestrated underground. In this paper, the main area discussed is the capturing process and application in steelmaking industry from economical point of view. Carbon capture is an expensive process which creates an indecisiveness among different parties to actually put the process in practice. However, this expensive process is not properly quantified which is the main motivation of this study to contribute to the cost quantification of carbon capture. Carbon capture is mainly divided to several methods namely membrane separation, oxyfuel combustion, absorption, adsorption, chemical looping combustion, calcium looping and cryogenic method. Despite of having many capturing methods available, there was no vivid or clear application at a large commercial or industrial scale of several methods which rendered them mooted for comparison's sake. Technologies that have gone beyond technological readiness level (TRL) 4 shall be considered since the relevancy of the comparison can benefit parties planning to spearhead or undertake CCS.
{"title":"Comparative Review Study on Different Carbon Capture Methods and Applications in Steelmaking Plant from Economical Point of View","authors":"Thinesh Shakkti Arul Rajoo, K. Elraies, U. Z. Husna, Juhairi Aris Muhamad Shuhili, Mohd Afandi Abu Bakar, Hazliza Haron, Ismail Mohd Saaid, J. Lee, M. N. Mohamad Ibrahim, S. B. Gogoi, A. Saeedi","doi":"10.4043/31540-ms","DOIUrl":"https://doi.org/10.4043/31540-ms","url":null,"abstract":"\u0000 One of the emerging areas in combatting environmental issue like global warming is carbon capture and storage (CCS) entices a solution by not limiting output of any operation. Carbon capture storage refers to the process of capturing or gathering carbon dioxide released into the atmosphere from various activities and injecting the captured gas underground (aquifer). CCS can be divided into 3 main stages namely capturing, transportation and storage. The carbon dioxide will be captured from a source, being transported and sequestrated underground. In this paper, the main area discussed is the capturing process and application in steelmaking industry from economical point of view. Carbon capture is an expensive process which creates an indecisiveness among different parties to actually put the process in practice. However, this expensive process is not properly quantified which is the main motivation of this study to contribute to the cost quantification of carbon capture. Carbon capture is mainly divided to several methods namely membrane separation, oxyfuel combustion, absorption, adsorption, chemical looping combustion, calcium looping and cryogenic method. Despite of having many capturing methods available, there was no vivid or clear application at a large commercial or industrial scale of several methods which rendered them mooted for comparison's sake. Technologies that have gone beyond technological readiness level (TRL) 4 shall be considered since the relevancy of the comparison can benefit parties planning to spearhead or undertake CCS.","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"101 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80873163","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}
Corrosion and materials degradation factors during normal and abnormal operating conditions are among the essential criterion in evaluating materials suitability for an offshore pipeline transporting treated gas and condensate with contaminants i.e. CO2, Materials resistant to wet H2S damage in accordance with ISO 15156 requirements and mercury. A thorough study was conducted to ascertain the pipeline section that will be exposed to sour service conditions due to substantial Materials resistant to wet H2S damage in accordance with ISO 15156 requirements level along the pipeline during certain transient scenarios. The study was conducted in view of fit-for-purpose solution and CAPEX optimization initiatives for the project. During certain transient scenarios, there is potential exposure to substantial H2S level under wet conditions for a certain pipeline length which increases materials susceptibility to wet H2S damage such as Hydrogen Induced Cracking (HIC)/Stepwise Cracking (SWC) and Sulfide Stress Cracking (SSC). Flow assurance modeling with compositional tracking module was used to determine the level of H2S along the pipeline where few potential scenarios leading to sour conditions were considered. Risk assessments were also conducted to ascertain the impact and mitigations for the scenarios. Based on studies, exposure to sour service conditions is expected at a partial length of the pipeline as the H2S level exceeds the sour service limit during specific transient scenarios. Specific mitigation measures involving chemical injection, process control and safeguarding and operating procedures were outlined. The study successfully demonstrated an optimized materials selection approach for the pipeline.
{"title":"Hybrid Pipeline Fit for Purpose for Multiphase Gas and Condensate Transportation","authors":"Nur Izyan Mukhtar, M. H. A Razak, Z. Jamil","doi":"10.4043/31453-ms","DOIUrl":"https://doi.org/10.4043/31453-ms","url":null,"abstract":"\u0000 Corrosion and materials degradation factors during normal and abnormal operating conditions are among the essential criterion in evaluating materials suitability for an offshore pipeline transporting treated gas and condensate with contaminants i.e. CO2, Materials resistant to wet H2S damage in accordance with ISO 15156 requirements and mercury. A thorough study was conducted to ascertain the pipeline section that will be exposed to sour service conditions due to substantial Materials resistant to wet H2S damage in accordance with ISO 15156 requirements level along the pipeline during certain transient scenarios. The study was conducted in view of fit-for-purpose solution and CAPEX optimization initiatives for the project. During certain transient scenarios, there is potential exposure to substantial H2S level under wet conditions for a certain pipeline length which increases materials susceptibility to wet H2S damage such as Hydrogen Induced Cracking (HIC)/Stepwise Cracking (SWC) and Sulfide Stress Cracking (SSC). Flow assurance modeling with compositional tracking module was used to determine the level of H2S along the pipeline where few potential scenarios leading to sour conditions were considered. Risk assessments were also conducted to ascertain the impact and mitigations for the scenarios. Based on studies, exposure to sour service conditions is expected at a partial length of the pipeline as the H2S level exceeds the sour service limit during specific transient scenarios. Specific mitigation measures involving chemical injection, process control and safeguarding and operating procedures were outlined. The study successfully demonstrated an optimized materials selection approach for the pipeline.","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"10 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86986120","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 of this paper is to explain the beneficial information obtained during a microbiological study of an oilfield survey, where molecular microbiology techniques where utilised. The inclusion of these techniques highlighted information that would have otherwise been missed and/or misinterpreted. The molecular microbiology techniques deployed during this survey included Quantitative Polymerase Chain Reaction (qPCR) and Next Generation Sequencing (NGS). The aim of PCR technology is to specifically increase a target (gene) from an undetectable amount of starting material. The first step is extraction of DNA from the sample, which will subsequently be subjected to the qPCR technology. During qPCR gene copies are made during thermocycling and a fluorescent marker accumulates, which can be used to quantify the target gene. Similar to the PCR technology, DNA is extracted from the sample and the DNA is amplified. In NGS, this is then sorted into a library of small DNA segments before they are amplified. During the sequencing step each DNA fragment amplified is sequentially identified from light signals emitted by comparing with a DNA library. The results obtained indicated crucial additional information that was not detected by traditional methods. In addition to much higher, truer quantification of known populations of Total Prokaryotes and Sulphate Reducing Prokaryotes, identification of other groups of DNA was possible through the NGS technique analysis. The results provided valuable information, which has subsequently been used to apply successful, targeted mitigation strategies to reduce the risk of MIC to assets.
{"title":"Oilfield Microbiology: Case Study of Molecular Techniques for Determining the Risk of Microbiologically Influenced Corrosion MIC","authors":"Douglas Grant Bennet","doi":"10.4043/31498-ms","DOIUrl":"https://doi.org/10.4043/31498-ms","url":null,"abstract":"\u0000 The objective of this paper is to explain the beneficial information obtained during a microbiological study of an oilfield survey, where molecular microbiology techniques where utilised. The inclusion of these techniques highlighted information that would have otherwise been missed and/or misinterpreted.\u0000 The molecular microbiology techniques deployed during this survey included Quantitative Polymerase Chain Reaction (qPCR) and Next Generation Sequencing (NGS).\u0000 The aim of PCR technology is to specifically increase a target (gene) from an undetectable amount of starting material. The first step is extraction of DNA from the sample, which will subsequently be subjected to the qPCR technology. During qPCR gene copies are made during thermocycling and a fluorescent marker accumulates, which can be used to quantify the target gene.\u0000 Similar to the PCR technology, DNA is extracted from the sample and the DNA is amplified. In NGS, this is then sorted into a library of small DNA segments before they are amplified. During the sequencing step each DNA fragment amplified is sequentially identified from light signals emitted by comparing with a DNA library.\u0000 The results obtained indicated crucial additional information that was not detected by traditional methods. In addition to much higher, truer quantification of known populations of Total Prokaryotes and Sulphate Reducing Prokaryotes, identification of other groups of DNA was possible through the NGS technique analysis. The results provided valuable information, which has subsequently been used to apply successful, targeted mitigation strategies to reduce the risk of MIC to assets.","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82931401","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}
Chun Ho Leow, Hock Guan Ong, Rachel Lee, C. A. Khoo
This paper will present corrosion management of a wet sour gas carbon steel export pipeline using continuous and batch corrosion inhibitors with mono-ethlene-glycol (MEG) as hydrate mitigation strategy in NACE MR 0175/ ISO 15156 region 3 (severe sour). The wet sour gas carbon steel export pipeline corrosion management via continuous CI and batch inhibitors with closed loop MEG regeneration system is rare worldwide. This is especially challenging when the case study may potentially be the longest wet sour gas, large diameter carbon steel pipeline (approximately 207km × 32 inch) in the world thus far. Pipeline corrosion management and hydrate management aspects when being reviewed holistically, it could provide significant cost savings yet safeguarding the overall technical integrity of the pipeline. The overall corrosion management leverages on Shell's many years of JIP and operating experience in sour service including the pipeline material specification, corrosion management, inspection, and maintenance philosophy. Reliable correlation between reservoir properties and uncertainties severe sour service, flow assurance, chemical behavirous, operating experiences etc were considered to best represent the operating envelope for this wet sour gas carbon steel pipeline. This includes the testing and selection of continuous CI and batch inhibitor, corrosion monitoring, operational pigging, maintenance, and inspection requirements throughout the field life.
本文将介绍在NACE MR 0175/ ISO 15156区域3(严重酸性)中，使用含单乙二醇(MEG)的连续和间歇缓蚀剂作为水合物缓蚀剂的湿酸性气体碳钢出口管道的腐蚀管理。采用连续CI和间歇式缓蚀剂加闭环MEG再生系统对湿式酸气碳钢出口管道进行腐蚀管理，在世界范围内尚属罕见。当案例研究可能是迄今为止世界上最长的湿酸气大直径碳钢管道(约207公里× 32英寸)时，这尤其具有挑战性。从整体上看，管道腐蚀管理和水合物管理方面可以节省大量成本，同时保证管道的整体技术完整性。全面的腐蚀管理利用了壳牌多年的JIP和酸性服务的操作经验，包括管道材料规范，腐蚀管理，检查和维护理念。储层性质与不确定性之间的可靠相关性、高含酸工况、流动保证、化学行为、操作经验等被认为是这条含酸湿气碳钢管道的最佳运行包线。这包括连续CI和间歇抑制剂的测试和选择、腐蚀监测、作业清管、维护和整个油田生命周期的检查要求。
{"title":"Corrosion Management of Wet Gas Sour Gas Carbon Steel Pipeline with Corrosion Inhibitor and Mono-Ethylene-Glycol in NACE Region 3","authors":"Chun Ho Leow, Hock Guan Ong, Rachel Lee, C. A. Khoo","doi":"10.4043/31512-ms","DOIUrl":"https://doi.org/10.4043/31512-ms","url":null,"abstract":"\u0000 This paper will present corrosion management of a wet sour gas carbon steel export pipeline using continuous and batch corrosion inhibitors with mono-ethlene-glycol (MEG) as hydrate mitigation strategy in NACE MR 0175/ ISO 15156 region 3 (severe sour). The wet sour gas carbon steel export pipeline corrosion management via continuous CI and batch inhibitors with closed loop MEG regeneration system is rare worldwide. This is especially challenging when the case study may potentially be the longest wet sour gas, large diameter carbon steel pipeline (approximately 207km × 32 inch) in the world thus far. Pipeline corrosion management and hydrate management aspects when being reviewed holistically, it could provide significant cost savings yet safeguarding the overall technical integrity of the pipeline. The overall corrosion management leverages on Shell's many years of JIP and operating experience in sour service including the pipeline material specification, corrosion management, inspection, and maintenance philosophy. Reliable correlation between reservoir properties and uncertainties severe sour service, flow assurance, chemical behavirous, operating experiences etc were considered to best represent the operating envelope for this wet sour gas carbon steel pipeline. This includes the testing and selection of continuous CI and batch inhibitor, corrosion monitoring, operational pigging, maintenance, and inspection requirements throughout the field life.","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"48 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83386677","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}
There is high demand for water shutoff in quite a few SAS completed horizontal wells in the Bohai Bay, China. The popular swellable packer in combination with the ICD screen method cannot be adopted because segmentation cannot be achieved in the annulus between the SAS and the borehole wall by the swellable packers for the SAS is unable to be tripped out. A conformance control method is introduced and a case study is provided. When the SAS string is not tripped out, first the path for the particles to flow through is established by perforation. Then, a string of ICD screen with smaller diameter is run in place, followed by the pumping of the continuous pack-off particles into the annulus (the inner annulus) between the ICD screen and the SAS. Meanwhile, the particles being carried by the fluids also pack the annulus (the outer annulus) between the SAS and the borehole wall through the penetrations on the SAS. Thus, the function of axial channeling prevention is realized by the rings of particles. The well in the case study is an old well that suffered from high water cut, sand production and mud clogging simultaneously. For this operation, the filling rate of the particles was 104.2%, indicating the particles were tightly packed in the inner and outer annuluses and segmentation in the production interval was realized. After commissioning, the water rate dropped from the original 638m3/d to 85m3/d. The oil rate resumed to the level before the well was shut in and later slowly increased to 40.3m3/d. Water shutoff and oil enhancement was realized and neither sand production nor mud clogging occurred. Three functions are realized via the adoption of this method. Firstly, water shutoff and oil enhancement are realized via conformance control; secondly, both rings of particles together with the filtering layers in jacket provide better sand control; thirdly, the rings formed by the tightly packed particles are capable of preventing mud clogging. In this paper, perforation is innovatively proposed to establish the path for the particles to flow through so that both annuluses are tightly filled by particles, together with the ICD screens, conformance control is realized along the entire production interval and the target of water shutoff and oil enhancement is achieved. Accordingly, high CAPEX for sidetracking is avoided and the single well ROI is improved.
{"title":"Application of Conformance Control in Stand-Alone Screen SAS Completed Horizontal Wells-A Case Study of Bohai Bay","authors":"Xu Zheng, Y. Lei, Bailin Pei, Wei Zhao","doi":"10.4043/31611-ms","DOIUrl":"https://doi.org/10.4043/31611-ms","url":null,"abstract":"\u0000 \u0000 \u0000 There is high demand for water shutoff in quite a few SAS completed horizontal wells in the Bohai Bay, China. The popular swellable packer in combination with the ICD screen method cannot be adopted because segmentation cannot be achieved in the annulus between the SAS and the borehole wall by the swellable packers for the SAS is unable to be tripped out. A conformance control method is introduced and a case study is provided.\u0000 \u0000 \u0000 \u0000 When the SAS string is not tripped out, first the path for the particles to flow through is established by perforation. Then, a string of ICD screen with smaller diameter is run in place, followed by the pumping of the continuous pack-off particles into the annulus (the inner annulus) between the ICD screen and the SAS. Meanwhile, the particles being carried by the fluids also pack the annulus (the outer annulus) between the SAS and the borehole wall through the penetrations on the SAS. Thus, the function of axial channeling prevention is realized by the rings of particles.\u0000 \u0000 \u0000 \u0000 The well in the case study is an old well that suffered from high water cut, sand production and mud clogging simultaneously. For this operation, the filling rate of the particles was 104.2%, indicating the particles were tightly packed in the inner and outer annuluses and segmentation in the production interval was realized. After commissioning, the water rate dropped from the original 638m3/d to 85m3/d. The oil rate resumed to the level before the well was shut in and later slowly increased to 40.3m3/d. Water shutoff and oil enhancement was realized and neither sand production nor mud clogging occurred. Three functions are realized via the adoption of this method. Firstly, water shutoff and oil enhancement are realized via conformance control; secondly, both rings of particles together with the filtering layers in jacket provide better sand control; thirdly, the rings formed by the tightly packed particles are capable of preventing mud clogging.\u0000 \u0000 \u0000 \u0000 In this paper, perforation is innovatively proposed to establish the path for the particles to flow through so that both annuluses are tightly filled by particles, together with the ICD screens, conformance control is realized along the entire production interval and the target of water shutoff and oil enhancement is achieved. Accordingly, high CAPEX for sidetracking is avoided and the single well ROI is improved.\u0000","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"23 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89439930","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 study presents a novel neural network model to explore its application in automatically interpreting subsurface faults from seismic images. A Wavelet Convolutional Neural Network (CNN) model that incorporates discrete wavelet decomposition is presented, and its capability in segmenting subsurface faults is analyzed. In this study, different neural network models are developed to compare their performance in segmenting subsurface faults. Sliced 2D seismic images are used as the input of the models. Pre-interpreted images with fault locations are used as the output of the models. Different CNN models are created using different pooling methods, including a traditional U-Net model with average pooling method, and an advanced Wavelet CNN model using wavelet pooling method. The results show that the Wavelet CNN model, which incorporates discrete wavelet transformation as the pooling layer, has the best performance comparing to traditional models in segmenting subsurface faults from input seismic images. It is more effective in saving edge features during pooling operations and outperforms the traditional U-Net model in segmenting subsurface faults from seismic images.
{"title":"Automatic Fault Segmentation Using Wavelet Convolutional Neural Networks","authors":"Xu Zhou, Qishuai Yin, Bin Wang","doi":"10.4043/31529-ms","DOIUrl":"https://doi.org/10.4043/31529-ms","url":null,"abstract":"\u0000 This study presents a novel neural network model to explore its application in automatically interpreting subsurface faults from seismic images. A Wavelet Convolutional Neural Network (CNN) model that incorporates discrete wavelet decomposition is presented, and its capability in segmenting subsurface faults is analyzed.\u0000 In this study, different neural network models are developed to compare their performance in segmenting subsurface faults. Sliced 2D seismic images are used as the input of the models. Pre-interpreted images with fault locations are used as the output of the models. Different CNN models are created using different pooling methods, including a traditional U-Net model with average pooling method, and an advanced Wavelet CNN model using wavelet pooling method. The results show that the Wavelet CNN model, which incorporates discrete wavelet transformation as the pooling layer, has the best performance comparing to traditional models in segmenting subsurface faults from input seismic images. It is more effective in saving edge features during pooling operations and outperforms the traditional U-Net model in segmenting subsurface faults from seismic images.","PeriodicalId":11011,"journal":{"name":"Day 3 Thu, March 24, 2022","volume":"11 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90716039","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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