Day 1 Tue, December 19, 2023最新文献

{"title":"Dissolver Treatments to Re-Instate Functionality of Subsurface Safety Valves in Water Injection Wells","authors":"S. Hatscher, N. Havrevoll, T. Herrmann, S. Gjersdal, D. Dzhuraev, M. Torsvik","doi":"10.2118/215187-ms","DOIUrl":"https://doi.org/10.2118/215187-ms","url":null,"abstract":"The Downhole Safety Valve (DHSV) integrity tests of two water injection wells on the Nova subsea oil field on the Norwegian Continental Shelf failed after one month in operation. One of the two wells, W-1, also showed issues with the Injection Master Valve (IMV). The objective was to re-instate the functionality of all compromised valves as soon as possible. First, the root cause for the malfunction was to be identified. Several hypotheses were developed and assessed, including mechanical and chemical issues. Both injectors (W-1 and W-4) are completed in the oil leg of the reservoir and have been cleaned up to rig before an injection test was conducted. The wells were then suspended for several months prior to initial start-up and commencement of water injection. Although wax inhibition was used during the clean-up, wax deposition at DHSV depth could not be fully discarded. Monoethylene glycol (MEG) has been deployed for hydrate mitigation after the injection tests and during initial well start-up. Pressure data indicated that at least partially, a column inversion within the tubing, from water to hydrocarbons, occurred during the suspension period. This observation gave support to that wax or hydrate deposition might restrict the DHSVs' flappers' movement. Based on this hypothesis, an operation with an Inspection Maintenance and Repair (IMR) vessel was planned, organized and conducted within five weeks after the failed tests. The treatment concept included not only a wax dissolver, but also MEG and heated fluids to combine the benefits of temperature as well as chemical dissolution towards either potential type of deposit. Both wells were treated from the vessel as per plan. The operation successfully re-instated the functionality of all three compromised valves, allowing to safely commence water injection into the reservoir.","PeriodicalId":502427,"journal":{"name":"Day 1 Tue, December 19, 2023","volume":"71 3","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-12-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139172378","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":"Riserless Intervention on Deepwater Gulf of Mexico Well increases contributing interval length by 10-fold","authors":"W. Hosein, M. Vick, T. Quy, M. Dada, J. Sierra, J. Cubides","doi":"10.2118/215179-ms","DOIUrl":"https://doi.org/10.2118/215179-ms","url":null,"abstract":"Well X is an oil producer in the Mississippi Canyon of the Gulf of Mexico. The well was originally designed as a smart downhole flow control (DHFC) completion that allowed split flow between two cased-hole frac-pack (CHFP) sand control completions. Unfortunately, the DHFC system failed, and the well must be produced with commingled flow from both zones. Over time the well's skin (frictional pressure loss across the completion screens) has increased to a point where the well's production rate needed to be reduced to limit erosion and maintain integrity of the completion. Well X receives pressure support from a downdip injector which has led to seawater production and introduced the risk of barium-sulfate scale. The well's previous scale prevention treatment expired at the end of 2022. The scope of the Riserless Light Well Intervention (RLWI) was to remediate skin and refresh the scale prevention treatment in both zones. The intervention required right scoping the well control and ancillary equipment to enable successful pumping and wireline operations on a sub-ambient well under elevated subsea and surface metocean conditions. Additionally, surveillance was necessary to assess damage and allocate contributions from each zone. Individual isolation of both zones was required for acid stimulation and scale treatment. Achieving this involved either setting plugs or installing isolation sleeves across the failed flow control device. Based on production logs, it was observed that the contributing interval of the lower zone had been reduced to about 10 ft despite having 110 ft of perforations. To address this, an acid stimulation with use of diverter pills was carried out on the lower zone which resulted in an increase in the contributing height to the full 110 ft, marking a greater than 10-fold increase. Furthermore, successful scale prevention treatments were administered to both zones to prevent barium sulfate scale deposition. Throughout the intervention, all wireline operations were carried out effectively under sub-ambient conditions without any hydrate problems, loss of well control, or seawater ingress. Acid stimulation bullheaded from surface aided in successfully treating non-contributing intervals with the use of diverter pills. The use of the collapse rated hoses along with other well control package modifications have enabled access to other sub-ambient wellwork in this field.","PeriodicalId":502427,"journal":{"name":"Day 1 Tue, December 19, 2023","volume":"41 2","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-12-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139172233","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":"Downhole Completion Challenges and Solution using Critical Nonmetallic Sealing Technologies","authors":"P. Asthana, Mohamed Larbi Zeghlache, Marwan Almulhim, A. Bukhamseen","doi":"10.2118/214487-ms","DOIUrl":"https://doi.org/10.2118/214487-ms","url":null,"abstract":"Many of the new completion technologies were introduced to address the challenges related to the increasing well complexity and the advancement in the downhole high-pressure high-temperature (HPHT) realm. This paper focuses on the evolution of Nonmetallic sealing technologies used in downhole completion tools, from the simple O-ring based chevron stacks to the energized hybrid composite seals. Furthermore, future advances in seal development are discussed to tackle the new corrosive challenging environments. A literature review and subject matter expert input were gathered to study the nonmetallic seal design technologies and tool applications. The topics covered include material selection; chemical and environmental resistance; mechanical design and characteristics; durability and abrasion resistance; rigors of verification and life validation testing; challenging corrosive downhole scenarios for seals; and harnessing the environment to create application-specific seals. Various categories of sealing functions are discussed, including tubing/annulus barriers, static/dynamic sealing configurations, and temporary/permanent applications. Sealing technology selection for every downhole tool in the completion string is crucial to ensure safety, reliability, and profitability of a well completion for its planned life. This paper provides a reference with guidelines and best practices for reservoir and production engineers. Often, collaboration projects between operators and service providers can help in developing tailored and advanced Nonmetallic solutions. An understanding of sealing technology will assist in efficient project execution and curated design assurance.","PeriodicalId":502427,"journal":{"name":"Day 1 Tue, December 19, 2023","volume":"315 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-12-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139171801","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":"Comparative Analysis of Well Deliverabilities Through Different Perforation Strategies in a Mature Field, Deployment of Completion Conveyed Underbalance Perforation – A Case Study","authors":"Mansoor Ansari, Muhammad Ijaz, Zulfiqar Ali Anjum, Sahir Inam, Muhammad Sana ul Hussnain, Rafi Ullah, Imran Shafee, Faisal Zia, Ibtihaj Atiq","doi":"10.2118/217355-ms","DOIUrl":"https://doi.org/10.2118/217355-ms","url":null,"abstract":"Wellbore deliverability impairment caused during drilling, testing, and completion operations remains an inevitable operational challenge. The TCP Shoot and Pull perforation method is widely deployed in the country; however, the requirement of kill cycle afterward ultimately hinders the perforation performance. On the other hand, underbalance perforations post well completion presents their challenges with limited IDs, compromised penetration (smaller gun size), and most importantly; maintaining underbalance in subsequent perforation runs. Therefore, the Operational Best Practices developed throughout the years needs to be tailored as per individual well requirement. The performance of the existing perforation methodology of TCP Shoot & Pull (Overbalanced) and Thru-Tubing (Underbalanced / Balanced) were evaluated for recently completed wells in a mature gas field. The well test interpretation indicated near wellbore damage in wells completed overbalance across the sandstone formation, significantly affecting the deliverability of the wells. Unlike most carbonates, Acid Stimulation is not readily adopted for clastic formations due to its associated risks, therefore, it becomes quintessential to identify suitable perforation techniques to improve well deliverability. Completion Conveyed Perforation guns were successfully deployed at the newly drilled development well, which showed significant improvement in the well's deliverability compared to the existing methods of perforation. This paper presents the successful application of Completion Conveyed Underbalance Perforations (CCUP) in development wells along with well performance improvement compared to previous strategies. The CCUP technique was risk assessed and selected for the new development wells in a mature gas field. The 4-1/2\" casing guns were conveyed with a drop-sub assembly in the permanent packer tail. Following well completion operation, underbalance was induced in the wellbore. The guns were successfully activated and dropped in rat-hole through Slickline.","PeriodicalId":502427,"journal":{"name":"Day 1 Tue, December 19, 2023","volume":"42 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-12-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139172231","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 Cement Design Assures Well Integrity Under Dynamic Stress","authors":"A. A. Mahmood, U. A. Jan, A. Y. Khan, Hassaan Rasheed, Jose Salazar, Khurram A. Shah, Shahjahan Khan","doi":"10.2118/217352-ms","DOIUrl":"https://doi.org/10.2118/217352-ms","url":null,"abstract":"The Kohat Plateau in Pakistan features major Gas and Condensate producing fields with majority of the blocks owned and operated by two of the country's biggest E&P Operators. Operators are known to frequently encounter severe drilling challenges, and over time, have devised certain technology solutions that have helped curtail the major drilling challenges to a good extent, helping improve the time and cost expended in reaching the target depths. However, the problems arising after the Drilling cycle – foremost being Sustained Casing Pressure (SCP) – require expensive remedial treatments and loss of production; this paper presents a solution to this particular challenge of SCP including in-depth cause analysis, treatment design and implementation. In the analysis stage, the drilling data of wells experiencing SCP in one of the Casing annuli was reviewed to pinpoint possible areas of compromised well integrity. It was observed that sections having good Cement bonds and sufficient Top of Cement in the annulus also became compromised over time, indicating operations conducted after the drilling phase could be responsible for the annular fluid migration, and hence SCP. It must be noted that extensive drill-stem tests to assess the reservoir economics as well as production pressures generate significant dynamic stress on the well structure. Through the use of custom stress-analysis software for annular Cement, it was concluded that it is this stress that causes the primary isolation of the constructed well, the annular Cement, to fail allowing annular migration of formation fluids. A new class of stress-resistant, auto-repair Cements was seen to resist any mechanical failure under stress enabling Operators to drill wells with lasting structural integrity. Mechanical properties including Young's Modulus, Poisson Ratio and Annular Expansion co-efficient were analyzed to design a Cement system capable of withstanding the applied stress. The first in-country application was conducted as the Intermediate-section Cementing in a new well. The system exhibited good isolation with average 10mV amplitude (free pipe amplitude 51 mV) in Cased Hole bond logs and no annular pressure is observed till date in the section more than 02 years after the primary cementing operation. This design approach was subsequently extended to other fields, with successful applications that reduced, and in certain cases, eliminated the need for remedial work. By presenting a detailed field application of flexible and self-healing Cement, the paper puts forth a general, stepwise approach for the selection of a Cement design that promises lasting annular isolation and minimizes the risk of communication behind the casing.","PeriodicalId":502427,"journal":{"name":"Day 1 Tue, December 19, 2023","volume":"207 ","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-12-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139171958","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":"Light Intervention Platform for 28,500-psi Environments","authors":"Rafael Rodriguez, Derek Copold, Mark Milkovisch, Christopher Babin, Rafael Ramirez, Ibrahim Ugah","doi":"10.2118/215185-ms","DOIUrl":"https://doi.org/10.2118/215185-ms","url":null,"abstract":"An operator, while designing their completion, needed to secure slim electrical-line intervention technologies, including shifting, debris removal, and milling services. Environmental challenges dictated the following requirements for intervention: 28,5000-psi pressure rating, 150°C temperature, 2.313-in. pass-through restriction, and sour service (H2S rating) as required by the operator. No slim electrical-line intervention technologies existed that met the sour high-H2S, high-pressure, small pass-through restriction requirements. However, upgrading an existing 20,000-psi slim electrical-line instrumented and automated intervention platform was an economical and technically feasible option that would meet the operator's requirements. The slim high-H2S and high-pressure upgrade was achieved by improving the pressure rating of critical components through a combination of using high-performance materials and optimizing the mechanical robustness by removing high-pressure stress concentrations. Functional and environmental tests were completed to validate the solution. This paper presents the analysis and development done to arrive at this solution, demonstrating how a flexible intervention architecture can be upgraded to expand its performance capabilities. The solution also enables future possibilities of expanding the platform to additional services such as tubing cutting and restriction navigation at pressures up to 28,500 psi.","PeriodicalId":502427,"journal":{"name":"Day 1 Tue, December 19, 2023","volume":"215 ","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-12-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139171956","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 Success Story of Using Deepwater Semisubmersible Drilling Rig for Workover Operation in 400 Meters Water Depth without Utilization of Anchoring System","authors":"Ronald Binilang, Batara Pande, Johanes Sare, S. Herputra, Massimo Rossi, Denny Prayogo, Colin Shanks, Damien Wee","doi":"10.2118/215177-ms","DOIUrl":"https://doi.org/10.2118/215177-ms","url":null,"abstract":"This paper will be focused on the engineering process for first-time experience workover operation in shallow water depth with a 6th generation semisubmersible drilling rig. The 6th generation semisubmersible drilling rig is designed for operations in water depths of up to 3000 meters, with a typical minimum water depth requirement of 600 meters. However, the operation described in this paper was conducted at a depth of 400 meters solely relying on the dynamic positioning (DP) stability system without any additional mooring and anchoring system. The paper will cover the environmental conditions, engineering processes for drilling rig qualifications, operations envelope, mitigation plan, summary of the drilling rig performance, and lesson learned during the campaign. The well was initially completed in 2019 by generation 4 semisubmersible drilling rig with mooring assistance. However, indications of decreased production performance prompted the need for a workover intervention to restore the original production indicators. The workover operation was planned after development wells at nearby field with water depth ranging between 1300-1500 m. The well test was requested after the completion phase, which includes utilizations of Through BOP Intervention Riser System (TBIRS) inside the drilling riser. Due to the presence of subsea facilities surrounding the well, it was not advisable to use an anchoring system to maintain stability, as it could pose hazards to the flow line or umbilical in close proximity to the well. Engineering preparation was made to qualify the capability of the rig to operate in the shallow water depth. Preliminary review showed technical concerns of deep-water drilling rig to operate below its minimum water depth. The key areas where then studied and assessed further to prepare for shallow operations include riser analysis and fatigue management (subsea Christmas tree, wellhead, and landing string component). Operation mitigation is then implemented thru dynamic positioning preparations, ESD management, rig heading, power generators reliability, riser angle and weather monitoring. Based on assessment of actual data, the rig was successful in maintaining the operational window in terms of static load and time series load management. Stable station keeping and desired heading was achieved for most of the time which has resulted on ensuring structural load and fatigue of subsea equipment within the safety margin. Key success factors were the engineering assessment, early stage of preparation, real time monitoring of manual and electrical parameters, DP3 reliability, electro-hydraulic control system and great teamwork while performing the job.","PeriodicalId":502427,"journal":{"name":"Day 1 Tue, December 19, 2023","volume":"429 ","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-12-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139172141","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":"Integrating Geochemistry with Other Reservoir Diagnostic Tools – Implications for Infill Planning and Development in the Midland Basin","authors":"O. Famubode, Nelson Acosta, Jana Bachleda, Cristhian Silva, Dana Gallegos, Beatriz Gomez, Muqing Jin, Shuangyu Ge, Tao Lv","doi":"10.2118/215901-ms","DOIUrl":"https://doi.org/10.2118/215901-ms","url":null,"abstract":"This study examined parent-child well interaction in three stacked producing formations in an unconventional field in the Midland Basin. By combining geochemical fingerprinting to determine which formations were being drained along with pressure interference analysis, microseismic data, petrophysical data, and production results, we identified important trends that may affect landing and spacing decisions in future infill drilling and multi-bench development plans. This paper describes a new workflow for integrating lithology, Oil-in-Place Index (OIPI), Rock Quality Index (RQI), and microseismic data to measure the influence of the parent wells on the child wells and the vertical drainage patterns of all the horizontal wells in the study area. Understanding these interactions and drainage volumes may lead to better field development planning and aid in decision making on the viability of field development projects.","PeriodicalId":502427,"journal":{"name":"Day 1 Tue, December 19, 2023","volume":"69 4","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-12-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139172008","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":"Considerations for Selecting Sustainable Corrosion Resistant Pipeline Solutions for the Oil & Gas Industry","authors":"Samuel Bouey, Aethan Sakell, Assaad Sakr","doi":"10.2118/214486-ms","DOIUrl":"https://doi.org/10.2118/214486-ms","url":null,"abstract":"This presentation will discuss how the existing corrosion resistant pipeline solutions measure against the performance characteristics required for safe and reliable corrosion-resistant pipelines in the oil and gas industry. This evaluation will survey the performance requirements of corrosion-resistant pipeline solutions considering technical, construction, economic and ESG (Environmental, Social and Governance) perspectives and will compare those requirements to the characteristics of the available corrosion-resistant pipeline systems. This presentation also includes a case study covering the use of an innovative factory lined carbon steel pipeline product in a produced water network for a global exploration and production company in the Rocky Mountain region of the USA. As the corrosion-resistant pipeline options are engineered systems that vary in construction, performance, economics and ESG characteristics, this presentation will highlight the advantages and disadvantages of the various corrosion-resistant pipeline options and will provide criteria for material selection in order to achieve safe and reliable corrosion-resistant pipelines within the oil and gas industry. This presentation will provide the pipelines professional with relevant considerations to support the decision-making process related to the material selection of corrosion-resistant pipelines.","PeriodicalId":502427,"journal":{"name":"Day 1 Tue, December 19, 2023","volume":"90 4","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-12-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"139172045","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}