Day 2 Tue, November 01, 2022最新文献

{"title":"The Power of Data - Unlocking Complex Value Across Petroleum Development Oman Through Six-Sigma Concept","authors":"Ahmed Al Salmi, Yousuf Al Zaabi, Nasser Al Kindi, Wayne Bryant, Carl Kays, Aisha Al Shukaili","doi":"10.2118/210826-ms","DOIUrl":"https://doi.org/10.2118/210826-ms","url":null,"abstract":"\u0000 Successful problem-solving is at the heart of any successful organization. The Six-Sigma problem-solving approach uses advanced data analysis techniques in conjunction with statistical testing to direct a team towards the problem solution. Since the introduction, the PDO Six-Sigma program has delivered >40 projects across 8 directorates, with projects making significant improvements across a range of diverse areas from Operational Carbon Reduction and Well Drilling Efficiency to HR response times and IT request efficiency.\u0000 The PDO Six-Sigma training and development team have designed a highly effective improvement that is focused on training and coaching staff to execute structured problem-solving projects across all corners of the organization. This advanced problem-solving program method and the rapid success it has delivered so far, makes it a leader in the Oil and Gas industry. The PDO approach is fully transferable and equally effective to any organization in Sultanate of Oman. The program is fully organized and coordinated internally by talented Omani coaches and has delivered significant, quantifiable benefits from day 1 (>$42m savings).\u0000 Six-Sigma capabilities are very rare in Sultanate of Oman, and the launch of this approach reinforces PDO's reputation as a leader in Lean & Continuous Improvement techniques. Since it's conception this small program has delivered >15 projects/year and (on average) savings of over $21 million per year for PDO, with some individual projects delivering >$2.5 million savings. The importance of this program for industry in Sultanate of Oman cannot be underestimated as it is now developed to a stage to be readily transferable if organizations have the same commitment to improvement. Several projects are already being replicated across internal directorates within PDO. In addition to the quantifiable cost savings, the program has also delivered customer satisfaction benefits as well as significant simplification and productivity improvements. PDO has been a pioneer in Sultanate of Oman in applying this approach effectively and efficiently. This overall technique, the training package, and the knowledge within the development team could be a game-changer and used as a catalyst to transform the industry in Sultanate of Oman. With very little investment, this approach could be replicated in almost any area of business from the Government sector to Manufacturing and Banking.\u0000 The PDO Six-Sigma approach is unique in Oil and Gas and highly innovative in Sultanate of Oman. The methodology rapidly drives data-based measurements to effectively identify and validate root causes and improvements to complex problems. Where many Continuous Improvement techniques rely on team-based judgment and knowledge to identify solutions, the PDO Six-Sigma approach steers the team using the power of data and statistical analysis – this has proven to be incredibly powerful and effective for PDO.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"24 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126558946","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}

{"title":"Anti-Foam Injection Optimization","authors":"A. T. Derebe, Salem Al Neyadi, Fadhal Mohsen Nasser, Ibrahim Al Nuaimi, Brama Damanik, Ahmed Ibrahim Romi","doi":"10.2118/211189-ms","DOIUrl":"https://doi.org/10.2118/211189-ms","url":null,"abstract":"\u0000 Habshan-5 & Sulphur Plant consists of two Rich Acid Gas Removal Units (AGRU) designed to process a total of 1340 MMSCFD of sour feed gas. These units utilize MDEA solution to produce close to H2S-free sweet gas. The objective of this study is to minimize the continuous dosing of anti-foam in the AGRUs without increasing the foaming tendencies, while maintaining sweet gas specifications. Consequently, leading to a significant reduction in the operating cost.\u0000 The method used was the reduction in anti-foam continuous dosing rate in a gradual manner. Each phase lasted for approximately one month, which gave enough time to stabilize the unit and collect sufficient reliable data. Meanwhile, several parameters were monitored on regular basis, such as foam height, foam breakdown time, absorber pressure drop and sweet gas quality. Parameters were gathered using laboratory analysis and PI ProcessBook software. These parameters were then compared against design values and trends analyzed before making decision to go ahead with the next phase or revert to earlier dosing rate.\u0000 In phase 1, anti-foam dosing rate was reduced from 90 L/hr. to 50 L/hr. Foam height remained below target of 20 cm and even showed slight reduction compared to before. All other parameters were within acceptable limits, and no noticeable changes compared to earlier data.\u0000 Anti-foam dosing rate in phase 2 was reduced from 50 L/hr. to 40 L/hr. The overall foam breakdown time for both units had a small drop, which indicated a slightly reduced foaming tendency. There were no changes in the other parameters.\u0000 The anti-foam dosing rate in phase 3 was reduced again from 40 L/hr. to 30 L/hr. All parameters were within the acceptable limits, and there were no changes compared to phase 2.\u0000 In phase 4, anti-foam dosing rate was reduced from 30 L/hr. to 20 L/hr. Foam height and breakdown time increased significantly to 100 cm and 100 seconds respectively. It was determined that maintaining dosing rate at 20 L/hr. would eventually lead to a foaming event. Thus, dosing rate was increased back to 30L/hr. permanently and trial was completed.\u0000 Overall anti-foam consumption was reduced by 53%. This initiative shows how decrease in operating costs can be achieved by optimizing chemical injection rate without jeopardizing the safety and integrity of the plant.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"28 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124845222","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}

{"title":"Well Integrity Surveillance with High Sensitivity Temperature Distributed Sensing","authors":"J. Chavarria, M. Grubert, C. Minto, Euan Adams","doi":"10.2118/211270-ms","DOIUrl":"https://doi.org/10.2118/211270-ms","url":null,"abstract":"\u0000 Increasingly well integrity monitoring is being done with fiber optic temperature and acoustic measurements. Historically temperature and acoustics have required two separate types of systems. Advances in fiber optic sensing have resulted in temperature measurements that can be conducted using an Interrogator Unit (IU) that is traditionally used for distributed acoustic sensing (DAS) acoustics analysis. The Rayleigh based Distributed Temperature (RDTS) measurements are sensitive to a 1/1000th of a degree and can be used to assess subtle integrity issues like leaks or problems in the various annuli of wells. It is this great sensitivity to small temperature fluctuations that is the focus of this paper. These DAS measurements have higher sensitivity than conventional DTS measurements and can illuminate previously unexplored wellbore dynamics.\u0000 Various measurements with fiber optic cables were conducted with DAS IU's in different engineering and downhole settings. The DAS measurements in wellbore conditions were processed for temperature focusing in the low frequency content of the signals. The measurements were initially validated against other sensing tools like DTS (Raman) and PT gauges to ensure that the temperature changes measured by the DAS unit are representative of real thermal regimes. Measurements were taken from a well setting that included permanent fiber optic cable cemented behind casing. However, these same tools are deployed in wells where the fiber is installed attached to the production tubing hence reducing deployment costs.\u0000 The DAS data processing was processed for temperature fluctuations by focusing on low frequency components where fluid regimes reside. Fluid movement within the wellbore was identified by small temperature changes recorded by the IU. These fluid dynamic processes were subtle and quiet enough that a traditional acoustic analysis was not able to identify anomalous zones. The resulting measurements were able to determine fluid velocities illuminated by temperature changes. We show how high sensitivity RDTS signals capture small temperature features and various fluid dynamic responses within the well not possible with other tools. The responses from the system clearly showcase quiet zones above which clear entry points of fluids can be identified as the origin of leaks.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"56 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124307857","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}

{"title":"Step Change in Drilling Performance Through Surface Automation in Onshore Abu Dhabi","authors":"Imad Al Hamlawi, A. Creegan, Nahum Ronquillo, L. Baptista, Mohamed Jalbout, Mouza Al Nuaimi, K. Azizuddin","doi":"10.2118/211789-ms","DOIUrl":"https://doi.org/10.2118/211789-ms","url":null,"abstract":"\u0000 The process of drilling an oil or gas well is inherently challenging due to the unpredictable nature of many of the variables at play. However, the overall process can be broken down into many smaller phases, each of which has a signature of repeatability. By automating the repeatable processes, and by optimizing the inputs that are a function of variable conditions, we can industrialize the drilling process at a higher level and drive toward consistent, high performance. Improving operational inefficiency requires long-term training or special tools to help address downhole issues. This can be costly and requires many man hours. In the pilot reviewed in this paper, a Surface Automation Solution was implemented to improve well construction performance. The Surface Automation Solution was comprised of a Drilling Automation Platform (DAP), a real-time Intelligent Drilling Optimizer (IDO), an automated stick slip mitigation system, and Automation Lifecycle Management (ALM) supporting services.\u0000 The Surface Automation Solution showed extraordinary performance, delivering efficient drilling connections, optimum drilling performance and mitigating drilling dysfunction. New records were achieved in every hole section where the system was operated, resulting in 51% overall ROP improvement compared to offsets, and 44% reduction in stick slip severity, translating to 3.2 rig days savings.\u0000 In this paper, we will examine how the Surface Automation Solution saves well delivery time by automating drilling activities, mitigating drilling dysfunctions and optimizing parameters to increase ROP on each section. The outcome is measured by the performance, which in this case is time saved. The data shown is the overall macro key performance indicator (KPI) along with the performance at each individual hole section.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"90 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121895560","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}

{"title":"Evolution of Well Completion Strategy in Deep High-Pressure Sour Environment to Enhance Rig-Less Operations & Optimize Rig Workover Operations","authors":"Hamood Al-Hajri, Anees Al-Subhi, F. Khayrutdinov, Asaad Al-Busaidi, Ibrahim Al-Shukaili, Humaid Al-Abri, Zahir Al-Abri, A. Al-Hadhrami","doi":"10.2118/211369-ms","DOIUrl":"https://doi.org/10.2118/211369-ms","url":null,"abstract":"\u0000 Deep critically sour fields played a key role in PDO's production portfolio for past two decades particularly in the south of Oman. Cost-effective solutions to develop these fields was certainly needed to ensure that oil produced from these fields is economically attractive. Completion design optimization was successfully implemented leading to significant savings in life-time cost of these well.\u0000 Completion optimization journey was performed in stages based on the challenges encountered throughout the life of the field. Due to risky nature of the reservoirs in these fields, wells were completed with tubing and permanent packers to ensure well integrity requirements are fulfilled and all operation risks are controlled. These permanent packers induced a big challenge during well intervention & workover as they have low success chances when it comes to milling. This base completion design was optimized including eliminating the use of permanent packers to achieve savings of about 5% in well cost at least 80% in well interventions.\u0000 At early stage of the field life, combining drilling caprock and reservoir section and casing them with the same liner was considered as a good saving in well drilling cost leading to total cost reduction of about 5% of total cost. However, this optimization increased cost of well intervention dramatically in these wells as the tubing and packer need to be retrieved to gain full access. In addition, challenges in milling the permanent packer have increased intervention cost even further. This first optimization done was to introduce a liner across the reservoir section of the same size as the tubing (Mono-bore completion). This optimization made the completion more Rig-less friendly and reduced well intervention cost by at least 80%. The second optimization done was to replace the permanent packers with Tie-back Polished Bore Receptacle (PBR). This has eliminated the requirement for packer milling without jeopardizing the sealing functionality of the permanent packer. This design was even optimized further to eliminate the possibility of failure of the permanent packer or PBR by introducing cemented completion. Cemented completion has also reduced total cost of drilling & completing the wells by 5% while maintaining the advantage to perform well activities and minimum cost.\u0000 These improvements in well completion strategy have reduced life-time cost of the well dramatically without jeopardizing well basic functional requirements and well integrity requirement. As a result of this work, production from these field became more economically attractive.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"81 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122532538","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}

{"title":"Machine Learning Model for Drilling Equipment Recommender System for Improved Decision Making and Optimum Performance","authors":"C. Kloucha, B. El Yossef, Imad Al Hamlawi, Muzahidin M Salim, Wiliem Pausin, Anik Pal, Hussein Mustapha, Soumil Shah, A. Hussein","doi":"10.2118/211731-ms","DOIUrl":"https://doi.org/10.2118/211731-ms","url":null,"abstract":"\u0000 The oil industry, in its constant strive to maximize gains out of operational data is constantly exploring new horizons where to combine the latest advances in data science and digitalization, into the areas where key decisions to drive economical and operational decisions reside with an aim at optimizing the capital expenditure through sound decision making. High volume operational data has been recognized as hiding many opportunities where the captured details these repositories that include real time logs and bit run summaries, provide a clear opportunity where to extract insights to support optimized decisions in terms of equipment selection to achieve the desired operational objectives.\u0000 Current possibilities within data science have opened the possibilities through viable solutions, which in this case, aims at providing advise on which equipment in terms of BHA and Bits to select, that would yield the desired outcome for a drilling run. The whole exercise being based on evidence gathered from previous runs where the details for the equipment, the relevant well characteristics, and the observed rates of penetration and the used parameters, are taken into consideration to provide the optimum combination to be implemented in new runs.\u0000 The present study describes the methodology in terms of data utilization, data science method development and solution deployment, with the associated issues that had to be addressed in order to provide a viable solution in terms of data utilization, technical validity and final user utilization, as well as a series of recommendations to be addressed within any such endeavors to assure the value addition.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"150 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131394142","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}

{"title":"Operational & Social Challenges of Sour Gas Well Testing Operation in Brown Field","authors":"Z. Ahmad, Abdullah Alhaj Al Hosini, Mohammed Ibrahim Al Janahi, Abdulla Mohammed Al Marzouqi, M. A. Siddiqui, Mubashir Ahmad, Anubhav Agarwal","doi":"10.2118/211379-ms","DOIUrl":"https://doi.org/10.2118/211379-ms","url":null,"abstract":"\u0000 Well testing operation of sour wells by flaring or flowing through existing pipe line network with limitations always consider as highly challenging in brown field. In this paper operational and social challenges considered during critical well testing operation during different phases.\u0000 For initial performance evaluation, completion and surface facilities were not designed as per expected well fluids specially in consideration of H2S, CO2 and elementary Sulphur. These wells located in congested developed field and special consideration regarding social risk analysis and mitigation were considered. Extensive H2S and SO2 dispersion modeling conducted to develop EPZ & EAZ for safe operation by utilizing latest safety equipment's.\u0000 Special scale treatment and down hole chemical injection adopted to cater tubing accessibility due to elementary Sulphur and other scale issues to improve flow assurance during well testing operation. Case study of condensate storge tank utilization with improved safety precaution will highlight the consideration of reservoir fluids for any well testing operation. High volatile Condensate handling at well site always be serious challenge and can be utilized with extensive HAZOP and better process safety controls.\u0000 Well intervention operation with High H2S for gas wells in presence of water aggravate corrosion and H2S cracking significantly for any type of metallic material. Special down hole plugs, wire line, E-line and sealing elements of pressure control equipment's designed and utilized during intervention operation along with utilizing of special chemical.\u0000 Well control is serious concern while flowing such wells due to catastrophic asset and environment impact. Special well control consideration needs to be in place for any well control scenario, this paper will cover all type of surface and subsurface consideration to improve the well & reservoir integrity.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"24 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131592365","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}

{"title":"A Structured Approach to Rejuvenate Service Life of Marine Structures","authors":"Manur Ajith Shenoy, T. Subramanian, Ibrahim Al Awadhi","doi":"10.2118/211123-ms","DOIUrl":"https://doi.org/10.2118/211123-ms","url":null,"abstract":"\u0000 Extending the life of aging assets is a demanding task, especially if they have been exposed to harsh marine environment. Jetty berthing structures commissioned in 1980s for exporting hydrocarbons in one of the gas processing plants were required to be operational beyond their design life to sustain business requirements. Rejuvenation of these critical assets was therefore embarked upon to safely and reliably extend their life by twenty more years. This paper discusses challenges confronted and structured approach followed in restoring the integrity and extending the service life of the aged structures.\u0000 Special assessment strategy was devised to overcome tough challenges such as limited availability of existing drawings, non-existent original design documents, absence of loading & equipment data, thick marine growth enveloping the structural members, lack of underwater inspection history, etc. To ascertain the current condition of structures, a detailed inspection plan was developed. Close Visual Inspection of splash zone and under water regions of jetty structures viz., loading platform, breasting & mooring dolphins, utility platform, pipe / access trestles, etc., was performed to detect corrosion, fatigue cracks, damaged members, marine growth, etc. In areas of identified or suspected damage, Non-Destructive Testing viz., LRUT, PEC, FMD techniques were employed to detect potential defects. Structural models reflecting as-is condition were developed based on inspection findings and through rigorous structural analyses viz., In-Place, Push-Over, Fatigue and Seismic analysis, the fit-for-purpose fitness of structures was evaluated for life extension.\u0000 Obstruction to visual examination of the structures due to excessive algae growth, inclement weather conditions to conduct surveys, limited berth availability, etc., presented further challenges that were successfully mitigated by unique inspection strategies. Inspection revealed localized corrosion of nearly 30% metal loss particularly in splash zone, while sub-sea segments exhibited a general metal loss of 10-15%. Wrapping system previously employed to mitigate corrosion had suffered damage. Structural members under water were found completely swamped with thick marine growth.\u0000 Structural capacities of members, joints and pile foundations were evaluated as part of In-Place analysis. Push-Over analysis was performed to ascertain the available reserve strength (RSR) up to collapse limit under extreme storm condition. Through Fatigue analysis, fatigue life of joints due to cyclic loading from oscillating waves were checked for any integrity concerns. Based on the assessment results, various potential vulnerabilities in the structure were identified.\u0000 Cost effective and fit-for-purpose corrective actions consisting of strengthening, modification and repair schemes were finalized. Modern techniques / devices to remove / prevent marine growth, and durable protective wrappings in highly corroded region","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"3 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130562511","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}

{"title":"API Pipeline SMS Assessment Program: Key Changes and Learnings from Initial Assessment Outputs","authors":"C. Frazier, S. Toth, Alexa S. Burr","doi":"10.2118/211185-ms","DOIUrl":"https://doi.org/10.2118/211185-ms","url":null,"abstract":"\u0000 The American Petroleum Institute (API) represents all segments of the natural gas and oil industry, aiming to accelerate safety and environmental progress across operations while meeting global demand for affordable, reliable, and cleaner energy. Through API and partnership with the U.S. Pipeline and Hazardous Materials Safety Administration (PHMSA), state pipeline regulators, and other interested stakeholders, pipeline operators developed API Recommended Practice (RP) 1173: Pipeline Safety Management Systems. API RP 1173 is designed to help operators create a management system structure to systematically manage pipeline safety and continuously measure progress to improve overall pipeline safety performance. The core principle of API RP 1173 is the \"Plan-Do-Check-Act\" cycle, and it requires an operator to periodically review their pipeline safety management system (PSMS) to the requirements of RP 1173 on a triennial cycle.\u0000 In collaboration with industry partners, API developed the not-for-profit Pipeline SMS Assessment Program in 2019 and fully launched the offering in January 2020. In the three years since its inception, API has facilitated 14 assessments of pipeline operators’ safety management systems against the requirements of RP 1173. In doing these 14 assessments, the process for completing assessments has been tested by operators of vastly different sizes, carrying a wide array of products, from very small steam utility operators to large liquids operators with operating regions across North America.\u0000 The industry has also identified specific trends relevant to API RP 1173 implementation in conducting these assessments. Specifically, it has created awareness around some areas pipeline operators continue to struggle with in creating a holistic PSMS: 1) ensuring that field-level personnel understands how their roles relate to safety performance relative to the company's PSMS; 2) incorporating learnings from external events into their PSMS so that similar incidents do not occur; 3) incorporating relevant and standardized PSMS requirements into agreements with service companies, and; 4) delineating what RP 1173 requirements mandate programmatic governance or policy within their PSMS (an industry learning).\u0000 In this manuscript, API will provide an overview of the PSMS Assessment Program and changes made since its inception, an examination of the key learnings from assessment outputs to date, and a description of how the program is providing a feedback mechanism to improve industry initiatives to help operators implement RP 1173.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"100 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123126922","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}

{"title":"North Kuwait Jurassic Gas Experience of Expanding Multistage Completion Strategy for Managing Deep Tight Gas Development Challenges","authors":"Mohamed Abdel-Basset, Y. Al-Otaibi, Taha Blushi, A. Al-Dhafiri, M. Al-Mutawa, Mamoun. E. Abdelbagi, A. Hadi","doi":"10.2118/211390-ms","DOIUrl":"https://doi.org/10.2118/211390-ms","url":null,"abstract":"\u0000 North Kuwait Jurassic Gas asset has strategic importance for Kuwait production strategy as the only non-associated gas producing fields in Kuwait. This paper demonstrates the added value, experience, challenges and lessons learned of recent paradigm shift in Jurassic tight gas wells’ completion strategy from cemented liner to multistage completion. A successful expansion of Multi-Stage Completion (MSC) technology has been achieved on field level led by integrated team efforts since early 2020 to date. This helps to enhance overall well production potential, selective stimulation, overcome reservoir and intervention operations challenges, and early production delivery.\u0000 The Jurassic gas asset produces mainly from deep high pressure and temperature, conventional and unconventional tight carbonate reservoirs. The recovery from such complex heterogeneous reservoirs is extremely challenging if conventional development strategies are applied.\u0000 Due to the high reservoir tightness, permeability contrast among different flow units and dual permeability effect (matrix and natural fractures), well productivity potential significantly depends on the effectiveness of subsequent stimulation treatments of such complex heterogeneous reservoir to improve well productivity and connect the natural fractures.\u0000 Selecting proper well completion is critical to overcome such reservoir challenges and ensure efficient acid stimulation treatments of such unconventional formations that need convenient diversion mechanism during the stimulation to enhance the productivity of each individual reservoir layer, and enable future flexibility of selective re-stimulation and reservoir management.\u0000 The asset team has applied a step change in completion strategy to open-hole HPHT multistage drop-ball completions using state-of-the-art MSC technologies including closable frac ports, full 3.5in monobore post milling and debris sub to protect the MSC string during upper completion operations. This is to overcome such reservoir complexity, eliminate wellbore cleaning and multiple perforation intervention operations challenges and risks, eliminate cement quality uncertainties, improve overall cost, and fast track well delivery to production to meet asset production target by significantly reducing operation time from approximately one month of plug and perf technique to less than one week of continuous and less subsurface intervention operations.\u0000 Total of 23 new Multi-stage completions were successfully installed in last 2 years including 4 systems in horizontal unconventional Najmah reservoir with overall good production results and significant improvement in selective acid stimulation (matrix and Fracturing), intervention operations efficiency and fast well delivery to production. Therefore, the asset plans to continue expansion in Multi-stage completion strategy.\u0000 Based on gained experience, an integrated protocol for multi-stage candidate well selection, staging design and installa","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"236 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132857832","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}