Day 2 Wed, March 20, 2024最新文献

{"title":"Improve CT Milling Operations with 20/20 Vision - Combined Downhole and Operational Data","authors":"W. B. Ott, L. T. Miller, M. V. Galateanu, R. T. Fairley, T. G. Thomas, J. Pursell, K. R. Scherer","doi":"10.2118/218292-ms","DOIUrl":"https://doi.org/10.2118/218292-ms","url":null,"abstract":"\u0000 This paper will compare milling plugs with surface weight versus downhole weight and torque utilizing a real-time data platform to minimize unplanned, non-productive time (NPT) and cost overruns. The conclusive findings of this North American plug drillout operation highlights how pairing downhole weight coiled tubing (CT) operational data and visualizing this information in real time improve operations.\u0000 The team performed a field study to determine the best approach to mill out plugs. They milled the first plugs using the company's standard operating procedures (SOPs), decisions on surface weight and circulating pressure, and then assessed the plug parts at the surface. After establishing a baseline, the company milled the remaining plugs using real-time downhole weight and torque, along with other essential operational data. The company assessed the plug parts once they all returned to the surface. This study will demonstrate the improved efficiencies and reduced risks provided by performing a millout with essential data in real time, compared to hoping for the best with limited data.\u0000 When the CT operator used surface weight to mill plugs, weight on bit (WOB) fluctuated significantly, resulting in the mill generating large plug parts. Once the CT operator started milling the plugs with downhole WOB, the WOB range tightened, and torque was 50 to 250 ft-lbf. The ability to utilize downhole WOB in real time, along with the other CT data, will give all parties at the wellsite and in the office the best opportunity to mill out frac plugs successfully and consistently. Using downhole WOB and torque with all other CT data in real time helps limit downhole operational risks inherent to CT plug millouts.\u0000 The ability to see the clear difference between milling out plugs using downhole WOB and torque versus surface weight in a real-time platform provides essential insight into how to reduce stuck pipe instances, increase efficiencies, and lower completion costs.","PeriodicalId":517791,"journal":{"name":"Day 2 Wed, March 20, 2024","volume":"137 24","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-03-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140284703","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":"Estimating the Importance of Nano-Silica Sealing Parameters for Remediating Leaks in CO2 Geological Storage","authors":"O. Olayiwola, Nabaladiomon Coulibaly, Ning Liu, Boyun Guo","doi":"10.2118/218367-ms","DOIUrl":"https://doi.org/10.2118/218367-ms","url":null,"abstract":"\u0000 In carbon capture and sequestration methods, the possibility of carbon dioxide leaking via fissures formed in the geological storage is a major worry. A major risk is anticipated while fixing a micro-annuli leakage in CO2 storage with smaller apertures. There is a need for a low-viscosity substance that can offer a strong, resilient seal. Sealing these leaks and stopping CO2 migration might be possible with a novel use of nano silica (NS) gel. The suitability of nano silica gel for sealing cement fractures was investigated in this work through laboratory testing. While examining the rheological properties of nano silica gels, it was found that the concentration of nano silica rose as the gel strength and yield point increased. Furthermore, it was discovered that when the concentration of nano silica rises, so do the sealing and leakage pressures, which are the pressures prior to and following CO2 breach, respectively. With a typical 15% nano silica concentration in gel, a sealing pressure gradient of 30 psi/in and a leakage pressure gradient of 3 psi/in at a leaking rate of 0.01 liter/min were found. The pressure performance increases from the starting pressure of 0 psi to the regeneration sealing pressure of 600 psi and the corresponding leakage pressure of 350 psi at 21% nano silica concentration when the test is repeated after a day without injection operation. This study offers a cutting-edge plan for fixing leaks in the geological storage of CO2 and cutting down on idle time while the sequestration process is underway.","PeriodicalId":517791,"journal":{"name":"Day 2 Wed, March 20, 2024","volume":"98 9","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-03-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140395311","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 Models to Predict Pressure at a Coiled Tubing Nozzle's Outlet During Nitrogen Lifting","authors":"S. A. Thabet, Ahmed Ayman El-Hadydy, M. Gabry","doi":"10.2118/218294-ms","DOIUrl":"https://doi.org/10.2118/218294-ms","url":null,"abstract":"\u0000 Optimizing bottom hole pressure is crucial for successful nitrogen lifting during clean-out phases after well interventions. Precisely predicting bottom hole pressure is vital for evaluating Inflow performance relationship (IPR) and optimizing operational parameters (e.g., nitrogen injection rate, Run in hole (RIH) speed, and CT depth) in real-time. Multiphase flow around the CT complicates physics-based pressure estimation. This effort aims to develop accurate machine learning models for predicting bottom-hole pressure at the CT nozzle during nitrogen lifting, especially in wells lacking down-hole gauges.\u0000 A machine learning model is developed using readily available parameters typically gathered during nitrogen lifting operations, which include wellhead flowing pressure, wellhead flowing temperature, bottom hole temperature, oil density, water salinity, production rate, water cut percentage, gas-oil ratio, nitrogen rate, gas gravity, and CT depth as inputs. This model is trained utilizing measured bottom-hole pressure data acquired from deployed memory gauges, serving as the model's outputs. Nine distinct machine learning algorithms—Gradient Boosting, AdaBoost, Random Forest, Support Vector Machines (SVMs), Decision Trees, K-Nearest Neighbor (KNN), Linear Regression, Neural Network, and Stochastic Gradient Descent (SGD)—are meticulously developed and fine-tuned utilizing data streams obtained from diverse well operations across 235 wells through data acquisition systems. This dataset is split into two subsets: 80% for training the algorithms and 20% for rigorously testing their predictive capabilities. Two cross-validation processes (K-fold and random sampling) are used to assess the performance of machine learning models.\u0000 The outcomes of the top-performing machine learning models, specifically Gradient Boosting, AdaBoost, Random Forest, SVMs, and Decision Trees, reveal remarkably low mean absolute percent error (MAPE) values when comparing their predictions of coiled tubing (CT) nozzle outlet pressure to actual measurements. These MAPE values stand at 2.1%, 2.7%, 2.8%, 6.6%, and 5%, respectively. Additionally, the correlation coefficients (R2) for these models are notably high, with values of 0.936, 0.906, 0.896, 0.813, and 0.791, respectively. Furthermore, machine learning models offer distinct advantages over conventional vertical lift performance curve correlations, as they do not necessitate routine calibration. Beyond this, these models demonstrated their ability to predict bottom-hole pressure across various operations using data that the models had never encountered during training. Predictions were compared to actual measurements, showing a strong alignment between the model's predictions and real-world bottom-hole pressure data.\u0000 This paper introduces novel insights by demonstrating how using a machine learning model for predicting CT nozzle outlet bottomhole pressure across diverse pumping conditions can enhance ongoing nitrogen l","PeriodicalId":517791,"journal":{"name":"Day 2 Wed, March 20, 2024","volume":"114 22","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-03-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140285101","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":"Successful Implementation of A Solids-Free Fluid Loss System Used in Coiled Tubing Operations in Argentina","authors":"Leonardo D. Gimenez, Enzo J. Betti","doi":"10.2118/218356-ms","DOIUrl":"https://doi.org/10.2118/218356-ms","url":null,"abstract":"\u0000 This paper highlights the successful implementation of a solids-free fluid loss system during Coiled Tubing (CT) interventions executed in the Austral Basin. This treatment contains a low-viscosity, solids-free, Relative Permeability Modifier (RPM) for lost circulation control during sand cleanout operations performed in these low-pressure reservoir wells where the Bottom Hole Pressure (BHP) exceeds the reservoir pressure. Avoiding fluid losses reduces the likelihood of getting stuck CT from settling sand or differential sticking.\u0000 Significant experience has been acquired in Argentina using this system to avoid fluid loss during interventions, and the correct system formulation has been defined based on field information, lab testing, and experience. This system was applied mainly during CT sand cleanout operations in cased gas wells with sandstone formations and severe fluid losses. Pills of RPM are pumped and forced into the fractured zone without any damage to the formation before carrying out the CT sand cleanout intervention.\u0000 RPMs are being formulated and used within the oil industry to help mitigate fluid losses during intervention. The objective is to decrease the relative permeability to water without any (or minimum) modification to the relative permeability to oil. This methodology can be applied in water-wet formations without oil permeability modification, and in the Austral Basin in Argentina, this implementation has demonstrated its benefits during workover interventions. Following RPM treatments, wells were cleaned out without any circulation fluid losses or stuck pipe issues, leading to the successful execution of planned well programs.\u0000 The findings of this study can benefit the oil and gas industry by offering a viable and alternative solution for the intervention of depleted gas wells where it is necessary to avoid any fluid losses to the formation during any workover or CT intervention.","PeriodicalId":517791,"journal":{"name":"Day 2 Wed, March 20, 2024","volume":"6 4","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-03-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140395098","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":"Frac Plug Forensics: Post-Fracture Plug Failure Root Cause Analysis and the Subsequent Impact on Stimulation Performance","authors":"Trent Pehlke, G. Simpson, Tamara Maxwell, Cassidy Chow, Charles Bourgeois, Joshua Stibbs","doi":"10.2118/218310-ms","DOIUrl":"https://doi.org/10.2118/218310-ms","url":null,"abstract":"\u0000 High-resolution acoustic imaging technology has been developed and deployed to assess the sealing performance of over 11,822 isolation plugs following perforation and fracturing operations. With this information, advanced stimulation performance analysis can be conducted to enable the optimization of future completion designs and well operations. This paper provides insight into how this technology works and showcases its visualization capabilities. Additionally, through case studies, this paper shares how major North American operators deploy acoustic imaging to assess and improve their stimulation performance analysis and completion design. These studies reveal foundational and actionable information regarding the performance of different plug designs run in active frac basins. Furthermore, the downstream impacts resulting from these findings such as stage uniformity and overall perforation growth were also analyzed and presented.\u0000 By integrating high-resolution acoustics with proprietary imaging and machine vision techniques, this technology provides operators with a 360-degree view of the entire lateral in hydraulically fractured wells. In a single run, sub-millimetric 3D point clouds of data are collected for precise measurements and high-resolution image generation to identify post-stimulation liner damage and breaches at plug locations. In addition to damage and breach identification, phase angle, wall loss, ovality, erosional pattern, and plug slip displacement distances are also precisely determined for a complete assessment of plug performance and zonal isolation.\u0000 Following a detailed analysis of this aggregate dataset, an insightful plug performance assessment was undertaken by analyzing the 3D point clouds of data at each plug location. Analysis of the high-fidelity renderings and precise measurements revealed a notable performance difference between four commonly deployed plug types used. Select plug types more frequently failed leading to a fully breached casing, while others experienced significant sealing element and casing erosion. Depending on the failure type, uphole, target, and downhole stages may be under or over-stimulated. These effects are quantified in aggregate when analyzing the wells Uniformity Index and perforation area growth.\u0000 This high-resolution acoustic imaging technology has been used to directly identify and assess plug location damage and breaches faster and more efficiently than legacy technologies. Using the aggregate data collected and through the integration of machine vision algorithms and advanced imaging software, a detailed stimulation performance assessment can be completed. With this dataset, completion design improvements can be made with confidence to decrease stimulation operation risks and increase frac efficiency.","PeriodicalId":517791,"journal":{"name":"Day 2 Wed, March 20, 2024","volume":"64 S293","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-03-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140394813","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":"ICD Completion Stimulation and Water Shutoff Using Inflatable Straddle Packers","authors":"S. R. Fajardo","doi":"10.2118/218345-ms","DOIUrl":"https://doi.org/10.2118/218345-ms","url":null,"abstract":"\u0000 This study describes how the deployment and operation of an inflatable straddle packer combined with a real-time coiled tubing (CT) downhole measurement system improved the productivity of a well by optimizing an intervention that required selective treatment of multiple zones. The objective was to have the selected products reach only the targeted inflow control device (ICD) while isolating the other ones.\u0000 The inflatable, resettable, configurable, CT-conveyed straddle packer was set up to isolate a portion of the production ICD completion and allowed precise injection of stimulation and water conformance chemicals in one run. This system is more precise than other methods of selective placement (e.g., chemical diverters) and only requires a slight amount of tension and/or set-down weight to operate under its different configurations (inflation, spotting, and injection). Its combination with real-time downhole measurement capabilities enabled rapid response and adjustments to the actual downhole conditions throughout the operation.\u0000 The assembly was run successfully and managed to selectively stimulate and shut off two different zones in one trip, thus avoiding the use of multiple plugs to isolate the different sections. The real-time downhole measurement casing collar locator module permitted accurately placing the straddle section in front of the ICD port, while inflatable packers and a flow control module isolated mechanically the rest of the completion to facilitate fluid placement. Using the software specifically designed for this application, in combination with a memory logger tool that enabled a more accurate post-job evaluation, it was confirmed that all treatment fluids were injected into the targeted ICD zones, preventing more-permeable sections from absorbing it and adding the flexibility to avoid injecting the fluid used for the inflation of the packers.\u0000 This case study proposes an innovative approach to integrating CT conveyance, telemetry, and mechanical wellbore isolation tools to enhance production in wells with challenging configurations. While a thorough design identifies the optimized execution strategy, this methodology allows reducing the time of operation execution and using the treatment chemical fluids in a cost-effective manner.","PeriodicalId":517791,"journal":{"name":"Day 2 Wed, March 20, 2024","volume":"30 S98","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-03-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140395180","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":"Unique Electric Line Deployed Mechanical Cutting, Milling and Pulling Solution Successfully Applied in a Complex Fishing Operation, Regaining Access to a Critical Well","authors":"S. Murchie, O. E. Magnussen, Tore Finnesand, Kristian Andersen, Peter Gaballa","doi":"10.2118/218329-ms","DOIUrl":"https://doi.org/10.2118/218329-ms","url":null,"abstract":"\u0000 An offshore injection well in an operating field situated in the Norwegian Continental Shelf was being used for secure dumping of old drill water and well debris, this being a critical resource in support of field operations. During a routine check of the functionality of the well's downhole safety valve (DHSV) it failed its seal test. A flow tube exercise tool was run to try and resolve the situation, however it proceeded to get stuck within the DHSV, preventing the valve functionality, blocking access to the well and hence rendering the well unusable until a solution was found.\u0000 The customer utilised all usual means to fish the exercise tool, with numerous slickline and e-line runs to jar and pull the fish proving unsuccessful. An assortment of high strength fishing tools were also used, including a high strength stroker providing as high as 100 Klbs force. This too was unsuccessful, proving brute force was not the solution. A detailed analysis of the situation was carried out to determine the probable cause, the extent of the challenges faced, and the appropriate solution options available. A thorough recovery plan was then devised based on a number of key steps and processes to be executed, with a decision tree created to aid operational progress. Steps included a means of determining the exact position of the core of the exercise tool. Bespoke tooling was also designed and tested to provide the securing, cutting and milling of several internal components of the exercise tool to enable it to be pulled free from the valve.\u0000 These e-line deployed solutions were highly innovative, providing extremely effective, precise, and controlled capabilities resulting in the flow tube exercise tool retrieval, in turn enabling further intervention operations and a subsequent re-completion to be carried out. As a result of the processes and solutions devised to recover the stuck exercise tool from this well, a new method for securely exercising DHSV flow tubes using strokers has been devised and applied as an alternate method by the operator.","PeriodicalId":517791,"journal":{"name":"Day 2 Wed, March 20, 2024","volume":"67 2","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-03-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140285073","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":"Restoring Production Via Non-Rig Deployed Wireline Technology","authors":"W. J. Diwaku, H. Sambo, J. M. Sonhi, A. A. Saadi, M. Wallach","doi":"10.2118/218362-ms","DOIUrl":"https://doi.org/10.2118/218362-ms","url":null,"abstract":"\u0000 Objectives/Scope: This paper details the challenges faced and the solutions deployed to restore production following failure of a formation isolation valve (FIV).\u0000 Methods, Procedures, Process: The FIV was installed to isolate the reservoir during the deployment of the Upper Completion. Once the wellhead, tree, and flowlines were hooked up, several attempts were made to open the valve to initiate production. Despite the planned pressure cycles being applied, the FIV did not open. It was suspected that there was fill/debris on top of the valve preventing its hydraulic activation. The failure of the FIV, and associated lost production, drove the team to develop a remedial intervention plan. The Operator and Business Partner team evaluated multiple alternatives before selecting a combined slickline and electric line tractor-deployed solution. The plan included a drift run to determine the wellbore condition above the FIV, followed by a cleanout run and the milling of the FIV Inconel ball-valve. Due to the high hole angle, a tractor was required to apply weight on the mill bit.\u0000 Results, Observations, Conclusions: After the removal of the wellbore debris using a slickline bailer and a suction tool deployed with electric line (EL), a tractor milling assembly was deployed that successfully milled through the FIV ball-valve. The successful milling operation saved approximately $30MM in Major Rig Work Over cost by bringing the well back to production levels in accordance with the pre-drill estimates.\u0000 Novel/Additive Information: This paper describes the process followed to design an optimal intervention plan, and the detailed planning and operational steps. The optimal engineered solution coupled with operational discipline during execution successfully brought the well back to production, minimizing the lost production cost while avoiding a costly rig-based intervention.\u0000 This paper also highlights the novel technologies utilized, the milling BHA configuration, specific lessons learned, and best practices recorded during the execution.","PeriodicalId":517791,"journal":{"name":"Day 2 Wed, March 20, 2024","volume":"33 S117","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-03-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140395090","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":"The Role and Benefits of Intervention-Based Production in the Energy Transition and the Drive to Net Zero","authors":"M. Billingham","doi":"10.2118/218369-ms","DOIUrl":"https://doi.org/10.2118/218369-ms","url":null,"abstract":"\u0000 This work is an effort to quantify the CO2 production reduction with intervention-associated production. A brief summary of possible savings has been presented (Billingham et al. 2023). There is a global drive to reduce CO2 production to meet net zero ambitions and limit global warming. Fossil fuels, including oil and gas, have been shown to be a major contributor to CO2 emissions leading to an ongoing drive for energy transition to \"greener\" energy sources. Within this scenario, however, world energy demand continues to increase with a significant percentage of the world's population in a state of energy poverty. The growth of green-based new energy is significant but alone will not be able to meet the world's near-term energy requirements. As such, oil and gas will remain an important energy source in the near to mid-term future.\u0000 To maintain and increase production there are two avenues, these being the drilling of new wells or the reduction in the decline of production in existing fields, which ideally will include increases in recovery factors. The industry states that the latter approach delivers the cheapest production with the lowest carbon footprint. It makes sense that the improved utilization of existing infrastructure can deliver this, and the associated cost of production has been quantified before (Billingham et al. 2023). This work assesses intervention-associated production techniques to quantify the CO2 production reduction associated with this production.\u0000 Beginning with a high-level perspective evaluating rig-based new well production increases compared to agile interventions, the work then assessed specific technologies and methods that can deliver the desired outcomes. For example, it has been estimated that using a lightweight intervention vessel (LWIV) could reduce the associated CO2 production by 80% when compared to performing the same activity from a modular drilling unit (MODU). Opportunity for further improvements were also investigated.\u0000 Operators have the challenge of meeting global energy demand and their net-zero ambitions. Intervention-based production should be an enabler in achieving this balance. This work will serve as an industry reference as to the benefits of intervention-based production during the ongoing energy transition and why it should be a key focus.","PeriodicalId":517791,"journal":{"name":"Day 2 Wed, March 20, 2024","volume":"86 12","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-03-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140395387","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":"Safe and Successful Restoration of Wellbore Accessibility by Wellhead Gate Valve Milling","authors":"K. Almulhem, M. Mubarak, A. Muhammad, A. Mansour","doi":"10.2118/218346-ms","DOIUrl":"https://doi.org/10.2118/218346-ms","url":null,"abstract":"\u0000 Well control has been one of the most important items in oil and gas production engineering. The wellhead plays a vital role in well control as it consists of many valves, including the master valve (MV), crown valve (CV), and wing valve (WV). The MV is the lower valve in the wellhead that is directly exposed to well pressure. Therefore, it's very important to ensure the valves holding in terms of functions tests and greasing. Passing the MV that is stuck in a partial closed position is considered a tremendous challenge, not only in well integrity but also for well intervention. The valve cannot be opened to allow for well intervention and cannot be totally closed to withstand well pressure to act as surface barrier in line with API standards. This challenge presents an opportunity to capitalize on milling the MV utilizing a gate valve drilling unit (GVDU). This paper presents a solution that addresses stuck valves across wellhead trees.\u0000 The conventional practice is to utilize either a workover (WO) rig or coiled tubing (CT) to mill the MV and secure the well to change a defective MV. However, it is more challenging when the well does not meet the minimum barrier requirements and the operation is costly. A new generation of GVDU has been deployed to especially mill such a stuck/defective MV, with no need to utilize (CT) unit nor a wireline (WL) unit -.\u0000 A 15K pneumatic GVDU has successfully been demonstrated and proven its ability to mill the gate valves to safely restore and gain wellbore accessibility. During the planning phase of this operation, several elements were considered to ensure safe and efficient execution, including conducting a series of peer reviews, comprehensive risk assessments along with well integrity and well intervention peer review team members. During the operation, several challenges have arisen such as rising pressure because of the compressed gas while run in hole (RIH), which was tackled by a modification of the gas bleed-off needle. Moreover, killing the well was challenging due to the fact the MV was in stuck position. Thus, a circulation path was added through pumping water,. Nonetheless, there were three main advantages through utilization of a GVDU; one of which was the easy and light rig-up. Second was safe and quick operation, which was completed in only 2.5 hours. Third was the cost optimization unless idea is to indicate that no cost was involved?\u0000 This success of this operation has unlocked the well potential after regaining wellbore accessibility. It also resolved the well integrity/control challenge in a safe, an extraordinary expedited intervention, a cost-effective method, and an environmentally safe and minimal environmental footprint.","PeriodicalId":517791,"journal":{"name":"Day 2 Wed, March 20, 2024","volume":"39 3‐4","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-03-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140395415","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}