Day 2 Wed, March 22, 2023最新文献

{"title":"Downhole Target Milling Characterization Coupled with Cumulative Sum Event Detection Algorithm Accelerates Automation of Coiled Tubing Operations","authors":"Santiago Hässig Fonseca, P. Ramondenc, N. Molero","doi":"10.2118/212914-ms","DOIUrl":"https://doi.org/10.2118/212914-ms","url":null,"abstract":"\u0000 Real-time downhole data from coiled tubing (CT) milling operations improved performance metrics including rate of penetration (ROP) and stall rates. Those data enabled new diagnostics such as detection of milling target interfaces. At the same time, characterization of milling targets improves detection of interfaces between two contiguous milling targets and enables real-time diagnostics of the milling motor, bit, and target. These new capabilities enable more cost-effective operations and automation.\u0000 The torque and applied thrust relationship provides a means of characterizing the milling curve along which a milling bottomhole assembly (BHA)—motor and mill bit—and milling target operate. Torque-thrust data from milling three types of downhole targets—cement, through-tubing bridge plugs (TTBP), and composite bridge plugs (CBP)—are used to characterize that relationship for each BHA-target pair. Torque-thrust slopes for cement and mechanical plugs were calculated based on milling data from seven different wells. These data provide expected values for future milling operations and a reliable means to identifying when the BHA transitions from cement to a mechanical target.\u0000 The torque-thrust slope of cement (six samples), TTBP (three samples), and CBP (three samples) targets average −0.10, −0.01, and −0.03 ft-lbf/lbf, respectively. Cement milling follows a steeper torque-thrust curve than TTBP and CBP, which is explained by a higher friction coefficient between mill bit and cement. The TTBP has hard metal slips that must be milled to release the plug; the CBP has minimal metal content and is designed for easier millout of body and slips. Those differences in material and build explain the difference in torque-thrust curve slope between mechanical plugs. Changes to mill bit and milling target condition, pump rate fluctuations, and downhole condition variations also trigger deviations in the torque-thrust behavior. An algorithm based on a cumulative sum (CUSUM) statistical method detects small shifts in acquisition channels based on current and previous data. The algorithm considers individual surface and downhole channels, estimates group statistics, and triggers event detection when the CUSUM drifts beyond predefined standard deviations of the mean. The algorithm automates real-time detection and visualization of tagging top of targets, active milling, and stall events. The algorithm is augmented by known BHA specifications to anticipate stall conditions based on maximum recommended differential pressure, thrust, and torque.\u0000 The algorithm detects downhole events 9−27 seconds before they are visually perceptible, accelerating reaction time. Its causal design allows real-time detection and can be ported to CT acquisition software. It can calculate metrics including ROP and stall rates almost instantly, either in real-time or in post-job analysis. A control decision model is proposed for extending event detection—tagging a target, starting milling","PeriodicalId":303929,"journal":{"name":"Day 2 Wed, March 22, 2023","volume":"22 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131564108","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":"Novel Coiled Tubing Post-Fracturing Cleanout of Unconventional Wells Without Downhole Motor: A Case Study from Argentina","authors":"Juan Martin Mirande, Giovanni Palombizio, Lucas Arevalo, Alejandro Marro, Marcelo Rodriguez, R. Krasuk, Matias Vecchietti","doi":"10.2118/212943-ms","DOIUrl":"https://doi.org/10.2118/212943-ms","url":null,"abstract":"\u0000 Unconventional wells that are completed with plug-and-perf fracturing techniques require coiled tubing (CT) to mill the plugs. In Argentina, CT must mill upwards of 60 plugs to bring the well into production. The CT downhole motors are leading contributors to service quality incidents because: 1) they mill challenging materials over extended periods of time, and 2) they limit the pump rate, which reduces cleanout effectiveness and increases the risk of stuck pipe.\u0000 A completion campaign selected soluble plugs instead of composite ones to improve efficiency. Initial CT runs were still completed with a milling bottomhole assembly (BHA) to address the risk of low plug solubility. However, as evidenced during the initial campaign runs, the plugs dissolved nearly completely, leaving only the steel buttons inside the well. Those buttons required a high pump rate to carry them to surface. Given the excellent plug dissolution and the fluid velocity requirement to clean out buttons, the BHA was simplified to an extended reach tool (ERT) and a customized, high-rate jetting nozzle, thus eliminating the downhole motor.\u0000 The new and simplified BHA extended the pump rate limit from an average of 3.8 to 4.5 bbl/min with no adverse effect on circulating pressure. The operator observed a tenfold increase in the number of plug buttons recovered at surface, which reduced the risk of stuck CT pipe during interventions in those wells. The cleanout speed was also increased, reducing total operating time by 25%, costs, and diesel consumption.\u0000 A special procedure was developed for the cases when the BHA encountered consolidated sand and plug debris during the operations, a situation that occurred an average of three times per well. To clean those accumulations, the pump rate was increased to generate high jetting energy and stronger ERT agitation, and the CT was run in hole at slow speed until tagging the solids. This procedure allowed passing all the restrictions found during the execution of the CT cleanout jobs. This approach also made it possible to clean wells with known casing deformations, a common situation in Argentina unconventional wells.\u0000 Over the course of 44 wells, 13 were cleaned with the simplified BHA. This new approach addressed the two main sources of nonproductive time before initiation of the project: BHA failures decreased from 16% to 8% and no CT stuck pipe event occurred.\u0000 This is the first published case study of a post-fracturing cleanout in an unconventional well without the use of a downhole motor and which, instead, combined soluble plugs and a tailored BHA. Eliminating the downhole motor in this application significantly improved operational reliability and efficiency. The use of this simplified BHA to clean the well down to total depth is only possible with a good dissolution performance of the plugs present in the well.","PeriodicalId":303929,"journal":{"name":"Day 2 Wed, March 22, 2023","volume":"124 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116331794","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":"Reducing Emissions for Extended-Reach Well Stimulation Without the Need of Intervention","authors":"T. Watkins, J. Najafov, E. Watson, S. Livescu","doi":"10.2118/212942-ms","DOIUrl":"https://doi.org/10.2118/212942-ms","url":null,"abstract":"\u0000 For most wells in North America, hydraulic fracturing is usually performed by plug-and-perf. It requires perforating guns, plugs and milling bottom hole assemblies (BHAs), large water volumes, as well as coiled tubing and friction reduction technologies such as vibratory tools or tractors, in the case of extended-reach wells. To reduce operational complexity, time, and cost time and meet Environmental, Social, and Governance (ESG) goals, operating companies are in a continuous search for alternative innovative fracturing systems. A new approach to traditional hydraulic fracturing is presented in this paper showing significantly improved project economics and lower environmental impact.\u0000 A contactless sleeve recognition technology, consisting of any number of compact programmable dissolvable darts, is used to open and close sliding sleeves without the need of well intervention technologies. The new fracturing system was used in a horizontal well with a 16,568-ft long lateral. In this well, darts enabled the opening of 133 sleeves. The darts have miniature electronic sensors allowing real-time monitoring of their exact location as they move through the well and real-time dart control to activate them before landing on their target sleeves. The details presented show the acoustic monitoring confirmation of stages being successfully treated, the high-definition ultrasonic confirmation of no erosion or casing deformation, and the darts dissolution after the treatment.\u0000 The significant advancement of this hydraulic fracturing technique made it possible to completely eliminate the need for coiled tubing in an extended-reach well, gain confidence in casing deformation risked areas, maintain maximum wellbore inner diameter (ID) before and after completion, eliminate issues of mechanical indexing, ensure continuous pumping without rate limitations, exclude milling operations and avoid casing erosion. The field data demonstrates the efficiency of the new fracturing technology that allows stimulation of horizontal wells without the need for well intervention. The article summarizes the field results of the hydraulic fracturing operation and quantifies its outcomes for sustainable resource development and strong financial results.\u0000 The industry is under increasing pressure to reduce project costs and environmental impact. The new fracturing system described in this paper becomes a more efficient alternative to traditional plug-and-perf technology. It allows for reduced risks and costs, enabling operators to successfully complete extended-reach wells without need of intervention, overcome issues of casing deformation, improve operational efficiency, enhance energy production and reduce environmental impact.","PeriodicalId":303929,"journal":{"name":"Day 2 Wed, March 22, 2023","volume":"9 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132418813","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":"Virtually Unplugging Perforations: High-Resolution Acoustic Imaging Enabling Statistical Analysis of Calibration and Post-Frac Perforation Entry and Exit-Hole Datasets.","authors":"G. Simpson, A. Mercer, M. Mantell, Charles Bourgeois, A. Battistel, Trent Pehlke, T. Littleford","doi":"10.2118/212908-ms","DOIUrl":"https://doi.org/10.2118/212908-ms","url":null,"abstract":"\u0000 High-resolution acoustic imaging technology provides operators the ability to extract submillimetric measurements of perforations at any depth into the casing wall. Due to its three-dimensional nature, submillimetric acoustic data permits the extraction of highly accurate area-based measurements at any radial distance into the perforation, with key distances at the inner and outer casing boundary. This novel technology is fluid agnostic and is unaffected by fluid opacity or clarity. The platforms robust 3D measurement capabilities have made it into an ideal means to evaluate casing and perforations in challenging environments such as hydraulically fractured wells. The integration of high-resolution acoustic imaging into numerous operators’ hydraulic fracture and completions evaluation workflows has resulted in a highly insightful aggregate submillimetric perforation dataset. This large dataset has led to the development of a method to virtually unplug perforations by using a well-specific \"perforation entry and exit-hole area correlation\". The correlation established can only be extracted using acoustic based imaging as it requires submillimetric resolution of both the ID and OD profile of each perforation Using this correlation, the resulting set of post-frac perforation exit-hole measurements improves an operators’ ability to complete a holistic well completion evaluation, even when well conditions cause perforations to be plugged. The outcome is improved operational insight through the ability to directly compare stages with plugged perforations to those without. This approach can be applied at any point in the well's life cycle, which allows operators to revisit assessments and virtually unplug obscured and proppant-filled perforations. The methodology requires a sound baseline knowledge of the performance of the downhole perforating charges. The baseline is commonly obtained through a calibration stage, which is a stage of charges that are shot but left unstimulated to provide the control measurements for the specific charge in the given well conditions. Current industry performance of downhole perforating charges is investigating through the aggregated dataset of calibration charges. To validate this solid-state acoustic technology and demonstrates its high degree of accuracy for entry and exit-hole perforation measurements, machined samples were scanned with this technology, and with a metrology-grade laser scanner for comparison. This paper presents a novel virtual unplugging methodology, enabled by highly accurate and validated entry-hole measurements, as well as other insights garnered from the aggregate analysis of the world's largest calibration perforation datasets.","PeriodicalId":303929,"journal":{"name":"Day 2 Wed, March 22, 2023","volume":"225 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124664219","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":"New Compact Series Tractor and Stroker / Tractor Technology Delivers Smart, High Performance Intervention Capabilities and Efficiencies to Restricted Rig Up Height Electric Line Operations","authors":"S. Murchie, Baard Tinnen, Gerald Mclnally, Arne Motland","doi":"10.2118/212931-ms","DOIUrl":"https://doi.org/10.2118/212931-ms","url":null,"abstract":"\u0000 Wellsites, in particular those offshore, often have limited mast or A-frame height availability for the rig-up and deployment of tools into and out of the well. This can often lead to limited choices in, or compromises to the technologies being deployed, or the efficiency in which a service can be executed. The challenge is more acute when deploying electric line tools in highly deviated or horizontal wellbores, where a tractor is required as part of the toolstring configuration for conveyance purposes.\u0000 Recent developments in electric line deployed tractor and powered mechanical intervention technologies have been significant, implementing a platform architecture to the design and construction of the tools and leveraging digitalization for enhanced in-well visibility, agility and dynamic control. This in turn has delivered improved component modularity and sharing, multifunctional integration, power management and ultimately the performance, efficiency and capability of the toolstring, be that of the tractor itself or when integrated with an additional powered mechanical tool such as a linear actuator or rotational device. A compact series of these tools has now brought these advancements to toolstrings specifically developed to address and optimize deployment on wellsites having limited or restricted rig-up height, offering string length reductions of 33% for the Tractor and 45% for the integrated Stroker/Tractor combination.\u0000 The intervention operations presented in this paper were to be executed as rigless operations, with the required lubricators and pressure control equipment positioned on the BOP deck of the platform. This presented a rig-up height limitation as low as 12.33 meters on one wellsite. Furthermore, some of the wells were deviated, e.g. 81° on one, 70° on the other, necessitating a Tractor in the toolstrings – a definite requirement or as a contingency. The first operation was multi-run, to deploy a plug, a mechanical tubing cutter, and finally a ballistic tubing puncher. Here, a compact Tractor was incorporated and activated on all three runs, conveying the toolstrings to task depth. The second operation was to pull a deep-set plug. Here, a compact Stroker/Tractor was incorporated. While the plug depth was reached and the stroker engaged without having to activate the Tractor, the string did hang up when coming out of the hole with the plug, this attributed to swelling of the plug element. To recover, the tractor was activated and used to push the stroker and plug a short distance down the well, following which it was deactivated and the string with plug successfully pulled out of the hole. The third operation incorporated straddle deployment and assembly as part of a leak detection and rectification sequence. This required several runs, deploying/assembling, and retrieving the straddle. The fourth operation was a multi run perforation deployment in a deviated well, carried out in a confined space between the hatch deck and ","PeriodicalId":303929,"journal":{"name":"Day 2 Wed, March 22, 2023","volume":"23 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"117225788","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":"Coiled Tubing Utilized to Aid Complex Well Recompletion","authors":"K. Rahimov, Patcharapun Soodsakorn, Gary Duguid, D. Thom","doi":"10.2118/212932-ms","DOIUrl":"https://doi.org/10.2118/212932-ms","url":null,"abstract":"\u0000 Coiled Tubing (CT) has been proven as a robust and reliable technology most used in the energy industry to address complex well intervention activities. CT intervention was selected as primary solution when an operators gas producing well in the North Sea had developed a leak in the A-Annulus. After careful assessment an operator had decided to de-complete the well and run new economical completion. The identified scope of work presented several major challenges. Scale built up at different wellbore sections necessitating hydraulically activated BHA for mechanical cleanout, pumping salt washer treatment below the collapsed completion section, and setting the plug to isolate the well for next stage were main objectives to achieve as to enable retrieval of an old completion. This paper describes the use of an integrated well remediation methods to aid in de-completing the faulty production tubular. Discussions taken place around accuracy of advanced cleanout software by comparing the predicted value over the actual data captured during the operation. The paper also gives the overview to BHA selection and justification for the different stage of the operation. It also highlights several contingencies that were developed to address the challenges that were not projected earlier.","PeriodicalId":303929,"journal":{"name":"Day 2 Wed, March 22, 2023","volume":"9 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114168547","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":"1.69-inch Electro-Mechanical Pipe Cutting Deployed on Digital Slickline","authors":"F. Heaney, Bryan David Powell, G. S. Mackay, Mathew Craig Mlcak","doi":"10.2118/212910-ms","DOIUrl":"https://doi.org/10.2118/212910-ms","url":null,"abstract":"\u0000 Digital slickline (DSL) has been deployed in the industry since 2013 (Loov et al., 2014 & Wiese et al., 2015) and has proven to be an effective tool to improve well intervention efficiency from the traditional two-unit slickline and eline model. Since initial deployment, the product has continuously expanded services with on-command explosive triggers, non-explosive setting tools, downhole anchors, surface readout (SRO) pulse neutron formation evaluation services, production logging, and multi-finger calipers. Numerous case study papers extol the DSL time savings, which leverages one slickline rig-up & down compared to multiple rig ups and downs when a slickline and a separate eline unit are dispatched to complete the same work scope. On complex interventions such as multiple tubular patches, these savings could be several days, especially if each unit required scheduling to be on location. (Heaney et al., 2020). Other papers (Koriesh et al., 2022) highlight the opportunities for deploying a small and lightweight slickline unit to address offshore platform limits that would not support the larger eline units. Additional benefits of DSL include reduced personnel on board (POB), fewer crane lifts, faster rig up & down, and increased cable speeds compared to eline. Although DSL has many attributes, it still uses a slickline cable, albeit coated, that has a much lower breaking strength than eline and has limited communication bandwidth; nevertheless, the efficiency savings on many interventions is transformative.\u0000 One service requested for DSL is a non-explosive pipe recovery device to reduce health, safety, and environmental (HSE) risks and provide cost containment in areas that require an explosive escort. One specific device proven effective in pipe recovery is the eline deployed electro-mechanical cutter, which can produce a complete flare-free machine shop quality cut that other pipe-cutting devices cannot match. There are multiple variations of the electric cutting tool, and all employ proprietary high-powered motors that allow the cutting blade to sever the tubular. The novel feature in this paper is a battery-powered 1.69-inch electro-mechanical pipe-cutting tool deployed on DSL or eline to cut pipe from 2.375 to 3.5-inch diameter that dominates many completions globally. The paper will discuss tool development details and verification testing to ensure a battery-powered device could sever the expected downhole tubulars.","PeriodicalId":303929,"journal":{"name":"Day 2 Wed, March 22, 2023","volume":"16 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126363748","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":"Utilizing Manually Tracked Variables to Derive Complex Equations in Real-Time Platforms","authors":"Waylin B Ott, Robert T Fairley, T. Thomas, J. Pursell, W. C. Ables, Manuel L Guzman","doi":"10.2118/212936-ms","DOIUrl":"https://doi.org/10.2118/212936-ms","url":null,"abstract":"\u0000 Many threshold metrics in the well intervention industry's standard operating procedures (SOP) require monitoring and tracking of difficult-to-sensor operational components. Gathering this important job data is challenging due to the cost and/or availability of technology. This paper will outline how manually tracked parameters can be applied to complex equations inside derived channels and used to make real- time decisions.\u0000 Traditionally important variables such as return rate, density, and viscosity are tracked and documented manually. These metrics are needed to calculate thresholds such as annular velocity, Reynolds number, and bottoms-up time to surface, all of which are required to ensure debris is effectively transported to the surface during coiled tubing operations. Using the previously mentioned derived metrics in a live platform, users can set up warnings and alarms to make real-time decisions. This methodology enables the user to easily capture manually tracked variables in a singular job data set for post-job evaluation.\u0000 Because the industry has traditionally relied on handwritten and manually tracked data, the acceptance of digitally calculated results based on manual inputs has become commonplace. What was once minutes of calculation time to obtain a snapshot view of job-specific variables is now instantly available and tracked throughout the job so that time-sensitive decisions can be made using snapshots and tracked deviations from the SOP thresholds. Readily available information enhances overall job performance. Real-time availability of job metrics to the equipment operator and remote engineering support makes completions\u0000 cleaner, reduces stuck instances and non-productive time (NPT), optimizes chemical usage, and maintains rate of penetration (ROP).\u0000 True identification of annular velocity in singular and multi-sized casings, measurement of turbulent flow, and fluid balance status determine the ability to remove cuttings from a wellbore, which reduces the overall job time and the production testing costs post-intervention. Job performance metrics can be set and analyzed during operations. Any changes to the project scope can be assessed onsite or remotely to ensure acceptable deviations will not negatively impact the project outcome.\u0000 In previous years, technical papers have outlined how to optimize coiled tubing drillout efficiencies using SOPs, complex equations, and thresholds regarding fluid metrics, circulation times, differential pressures, and annular velocities. Still, these papers included manually tracked channels to document metrics for specific projects. Using the previously mentioned methods, manually tracked channels will display trends in complex equations, resulting in an improvement of the quality of data in a real-time platform and overall operational enhancement.","PeriodicalId":303929,"journal":{"name":"Day 2 Wed, March 22, 2023","volume":"81 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133333861","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":"Casing Leak Repair to Continue Hydraulic Fractures Stimulation","authors":"Gaston Oscar Ciminari, G. Cabo, German Rimondi, Diego Duran, Martin Nebiolo","doi":"10.2118/212933-ms","DOIUrl":"https://doi.org/10.2118/212933-ms","url":null,"abstract":"\u0000 A casing leak repair alternative is presented to allow continued hydraulic fracture treatment of an unconventional formation. Analysis of diagnostic operations, selection of the best alternative, and the results are detailed.\u0000 This paper details the diagnostic operations (annular circulation test, multifinger caliper log, leak chase with hydraulic packer on Coiled Tubing, fluid transit evaluation, and real-time camera downhole images acquisition) to identify the casing leak zone and the analyzed repair alternatives with the final selection of a casing patch.\u0000 To verify the pipe body shield strength and burst pressure post-patch expansion, a finite element analysis in dynamic condition was carried out to limit the hydraulic fracture pumping parameters.\u0000 This paper covers details on repair operations executed, verification analysis to confirm original frac treatment continuity, and lower & upper completion installation.\u0000 The diagnostics operations allowed pinpointing casing leak detection and selection of possible repair alternatives. The repair was carried out as planned involving many services companies.\u0000 A solution was implemented with local staff and services considering the COVID context with travel restrictions of the patch owners. Web broadcasting CT surface parameters allowed real-time support from casing patch suppliers during the entire intervention.\u0000 The completion plan with 24 frac stages performed through the casing patch was successfully executed.\u0000 The production packer with an OD of 99.5% of the casing patch drift was run through the casing patch and wireline set without any problem.\u0000 Considering well integrity conditions throughout the entire well production life as the main intervention objective, this paper introduces a successful alternative to repair casing failures on an unconventional well that allowed hydraulic fractures continuity to accomplish the original frac plan.\u0000 The well production was higher than the Estimated Ultimate Recovery (EUR) expected for the landing zone.","PeriodicalId":303929,"journal":{"name":"Day 2 Wed, March 22, 2023","volume":"40 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114893620","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 Tailor-Made Approach for Temporary Well Suspension Saves Cost for Remedial Stimulation and Well Activation: A Case Study from Northern Kuwait","authors":"Mohammed Ahmad Mohammed AlMatar, Zakaria Al-Bahar, Fahad Mahmoud Bastaki, Mizan BinOmar Chong, Jassim Hamed Barki, M. Jamal, Mehanna Al-Mehena, Mohamed Hedi Slama, K. Badrawy, N. Molero, V. Pochetnyy, M. Adel Sebaih","doi":"10.2118/212899-ms","DOIUrl":"https://doi.org/10.2118/212899-ms","url":null,"abstract":"\u0000 Following the rig-based well testing stage, completion programs of high-pressure wells in North Kuwait call for well killing with heavy oil-based mud (OBM). The workover rig is then demobilized, and production flowlines are installed. Well activation plans are carried out riglessly, and coiled tubing (CT) is instrumental to bringing the wells back to sustainable production. One of the major drawbacks from this practice is the formation damage generated by the OBM, which often requires additional interventions for remediation.\u0000 To address this limitation, a new approach leveraging instrumented CT for temporary well suspension was recently implemented. Real-time downhole telemetry is enabled by an optical line installed in the CT pipe and used to accurately set a through-tubing inflatable packer (TTIP). Once the latter is anchored at the planned depth, above the interval open to the formation, CT is disconnected from the packer assembly, and the fishing neck is protected with a sand plug. CT is then retrieved to surface, and a slickline dump bailer is run to spot cement on top of the sand plug. Once the cement has set, CT is run to displace the wellbore to kill fluid.\u0000 Two pilot wells were selected to implement this new approach for temporary well suspension. Both wells had a maximum potential wellhead pressure in the order of 7,400 psi, and 15.0-ppg OBM was originally planned for well suspension purposes. Upon completion of the zonal testing program - which included initial stimulation, well activation, and flowback - instrumented CT was run with high- pressure rotary jetting to condition the TTIP setting depth and displace the wellbore with brine, after which, a shut-in wellhead pressure near 2,000 psi was observed. In the next CT run, TTIP was set close to the end of the production tubing, and critical stages, such as depth correlation, packer inflation, and packer anchoring testing were closely controlled via real-time downhole measurements. Additional verification of the TTIP effective seal was carried out before the CT was disconnected from the packer assembly through an inflow test relying on live downhole pressure monitoring. Once the TTIP released, the temporary suspension was completed following the methodology described above. Finally, the wells were observed at surface with zero pressure for more than 24 hours, receiving acceptance from the operator.\u0000 This alternative approach for temporary well suspension represents an innovative solution to bring wells back into production without additional restimulation or well activation. This methodology greatly relies on CT real-time downhole telemetry, and operators from the Middle East can benefit from the experience gained in this project.","PeriodicalId":303929,"journal":{"name":"Day 2 Wed, March 22, 2023","volume":"41 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130079257","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}