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Improve CT Milling Operations with 20/20 Vision - Combined Downhole and Operational Data 以 20/20 的视野改进 CT 铣削操作 - 井下数据与操作数据相结合
Pub Date : 2024-03-12 DOI: 10.2118/218292-ms
W. B. Ott, L. T. Miller, M. V. Galateanu, R. T. Fairley, T. G. Thomas, J. Pursell, K. R. Scherer
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. 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. 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. 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.
本文将利用实时数据平台,比较使用地面重量与井下重量和扭矩铣塞的效果,以最大限度地减少计划外非生产时间(NPT)和成本超支。这次北美堵头钻孔作业的最终结果突出说明了如何将井下重量盘管(CT)作业数据配对并实时可视化这些信息,从而改进作业。钻井队进行了一项现场研究,以确定最佳的堵塞钻出方法。他们使用公司的标准作业程序(SOP)、地面重量和循环压力决策铣出了第一个堵塞,然后在地面对堵塞部件进行了评估。在确定基线后,该公司使用实时井下重量和扭矩以及其他重要操作数据铣削剩余的井塞。塞子部件全部返回地面后,公司对其进行了评估。这项研究将证明,与利用有限的数据尽力而为相比,利用基本数据实时进行铣出可以提高效率,降低风险。当计算机断层扫描(CT)操作员使用表面重量铣削塞子时,钻头重量(WOB)波动很大,导致铣削产生大的塞子部件。一旦 CT 操作员开始使用井下 WOB 来铣塞,WOB 范围就会缩小,扭矩为 50 到 250 英尺 - 磅英尺。实时利用井下 WOB 以及其他 CT 数据的能力将为井场和办公室的所有人员提供成功、稳定地铣出压裂塞的最佳机会。实时使用井下 WOB 和扭矩以及所有其他 CT 数据有助于限制 CT 塞磨出固有的井下作业风险。在一个实时平台上,能够看到使用井下 WOB 和扭矩与地面重量铣出堵塞之间的明显区别,这对如何减少卡管情况、提高效率和降低完井成本提供了重要的启示。
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引用次数: 0
Estimating the Importance of Nano-Silica Sealing Parameters for Remediating Leaks in CO2 Geological Storage 估算纳米二氧化硅密封参数对补救二氧化碳地质封存泄漏的重要性
Pub Date : 2024-03-12 DOI: 10.2118/218367-ms
O. Olayiwola, Nabaladiomon Coulibaly, Ning Liu, Boyun Guo
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.
在碳捕获和封存方法中,二氧化碳通过地质封存中形成的裂缝泄漏的可能性是一大隐患。在孔径较小的二氧化碳封存中,要解决微孔泄漏问题,预计会有很大风险。因此,需要一种低粘度物质来提供坚固而有弹性的密封。使用新型纳米二氧化硅(NS)凝胶可能会密封这些泄漏点并阻止二氧化碳迁移。这项工作通过实验室测试研究了纳米硅胶用于密封水泥裂缝的适用性。在研究纳米二氧化硅凝胶的流变特性时,发现纳米二氧化硅的浓度随着凝胶强度和屈服点的增加而增加。此外,研究还发现,当纳米二氧化硅的浓度升高时,密封压力和泄漏压力也随之升高,密封压力和泄漏压力分别是二氧化碳破裂前和破裂后的压力。凝胶中的纳米二氧化硅浓度通常为 15%,在 0.01 升/分钟的泄漏率下,密封压力梯度为 30 psi/in,泄漏压力梯度为 3 psi/in。在 21% 纳米二氧化硅浓度下,在一天不进行注入操作后重复测试,压力性能会从 0 psi 的起始压力增加到 600 psi 的再生密封压力和 350 psi 的相应泄漏压力。这项研究为解决二氧化碳地质封存过程中的泄漏问题和减少封存过程中的闲置时间提供了一个前沿方案。
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引用次数: 0
Machine Learning Models to Predict Pressure at a Coiled Tubing Nozzle's Outlet During Nitrogen Lifting 预测氮气提升过程中盘绕油管喷嘴出口压力的机器学习模型
Pub Date : 2024-03-12 DOI: 10.2118/218294-ms
S. A. Thabet, Ahmed Ayman El-Hadydy, M. Gabry
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. 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. 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. 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
在油井干预后的清井阶段,优化井底压力对于成功举升氮气至关重要。精确预测井底压力对于实时评估流入性能关系(IPR)和优化作业参数(如氮气注入率、孔内运行(RIH)速度和 CT 深度)至关重要。CT 周围的多相流使基于物理的压力估算变得复杂。这项工作旨在开发精确的机器学习模型,用于预测氮气举升过程中 CT 喷嘴处的井底压力,尤其是在缺乏井下压力计的油井中。机器学习模型是利用通常在氮气举升作业期间收集的现成参数开发的,这些参数包括井口流动压力、井口流动温度、井底温度、油密度、水盐度、生产率、减水百分比、气油比、氮气速率、气体重力和 CT 深度作为输入。该模型利用从部署的存储压力表中获取的井底压力测量数据进行训练,作为模型的输出。九种不同的机器学习算法--梯度提升(Gradient Boosting)、AdaBoost、随机森林(Random Forest)、支持向量机(SVM)、决策树(Decision Trees)、K-最近邻(KNN)、线性回归(Linear Regression)、神经网络(Neural Network)和随机梯度下降(SGD)--都是利用通过数据采集系统从 235 口井的不同油井作业中获取的数据流精心开发和微调的。该数据集分为两个子集:80%用于训练算法,20%用于严格测试算法的预测能力。两个交叉验证过程(K 倍和随机抽样)用于评估机器学习模型的性能。表现最佳的机器学习模型(特别是梯度提升、AdaBoost、随机森林、SVM 和决策树)的结果显示,在将其对盘管 (CT) 喷嘴出口压力的预测与实际测量结果进行比较时,平均绝对百分比误差 (MAPE) 值非常低。这些 MAPE 值分别为 2.1%、2.7%、2.8%、6.6% 和 5%。此外,这些模型的相关系数 (R2) 也非常高,分别为 0.936、0.906、0.896、0.813 和 0.791。此外,与传统的垂直升降性能曲线相关性相比,机器学习模型具有明显的优势,因为它们无需进行常规校准。除此以外,这些模型还证明了它们有能力使用模型在训练过程中从未遇到过的数据来预测各种作业的井底压力。预测结果与实际测量结果进行了比较,结果显示模型预测结果与实际井底压力数据非常吻合。本文通过展示如何使用机器学习模型来预测不同泵送条件下的 CT 喷嘴出口井底压力,从而提高正在进行的氮气提升操作,提出了新颖的见解。利用机器学习模型可以更高效、快速、实时和经济地替代校准的垂直提升性能相关性。此外,这些模型还能很好地适应各种储层流体特性。
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引用次数: 0
Successful Implementation of A Solids-Free Fluid Loss System Used in Coiled Tubing Operations in Argentina 在阿根廷成功实施用于盘管作业的无固体流体损失系统
Pub Date : 2024-03-12 DOI: 10.2118/218356-ms
Leonardo D. Gimenez, Enzo J. Betti
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. 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. 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. 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.
本文重点介绍了在澳大拉尔盆地实施的盘管(CT)干预中成功实施无固体流体流失系统的情况。在井底压力(BHP)超过储层压力的低压储层井中进行清砂作业时,这种处理方法包含一种低粘度、无固体的相对渗透性改良剂(RPM),用于控制循环损失。避免流体损失可降低因沉积砂或差粘而造成 CT 卡死的可能性。阿根廷在使用该系统避免干预过程中的流体损失方面积累了丰富的经验,并根据现场信息、实验室测试和经验确定了正确的系统配方。该系统主要应用于砂岩地层和严重流体损失的套管气井的 CT 清砂作业。在进行 CT 砂层清理干预之前,先将 RPM 药丸泵入并压入压裂区,而不会对地层造成任何损害。石油行业正在配制和使用 RPM,以帮助减少干预过程中的流体损失。其目的是降低水的相对渗透率,而不对油的相对渗透率进行任何(或最小)修改。这种方法可用于水湿地层,而无需改变石油渗透率,在阿根廷 Austral 盆地,这种方法的实施已在修井干预过程中证明了其优势。在进行 RPM 处理后,油井被清理干净,没有出现任何循环液损失或卡管问题,从而成功执行了计划的油井计划。这项研究的结果可以为油气行业提供一个可行的替代解决方案,用于枯竭气井的干预,在任何修井或 CT 干预过程中都必须避免地层的任何流体损失。
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引用次数: 0
Frac Plug Forensics: Post-Fracture Plug Failure Root Cause Analysis and the Subsequent Impact on Stimulation Performance 压裂塞取证:压裂后堵塞故障根源分析及其对钻井性能的影响
Pub Date : 2024-03-12 DOI: 10.2118/218310-ms
Trent Pehlke, G. Simpson, Tamara Maxwell, Cassidy Chow, Charles Bourgeois, Joshua Stibbs
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. 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. 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. 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.
我们开发并部署了高分辨率声学成像技术,用于评估超过 11,822 个隔离塞在射孔和压裂作业后的密封性能。有了这些信息,就可以进行先进的激励性能分析,从而优化未来的完井设计和油井作业。本文将深入介绍该技术的工作原理,并展示其可视化功能。此外,本文还通过案例研究,分享了北美主要运营商如何利用声学成像技术来评估和改进其激励性能分析和完井设计。这些研究揭示了在活跃压裂盆地运行的不同堵塞设计性能的基础性和可操作性信息。此外,还分析并介绍了这些发现所产生的下游影响,如阶段均匀性和整体射孔增长。通过将高分辨率声学与专有成像和机器视觉技术相结合,该技术可为操作人员提供水力压裂井整个侧向的 360 度视图。在一次运行中,可收集亚毫米级三维点云数据,进行精确测量并生成高分辨率图像,以识别刺激后衬垫的损坏和堵塞位置的破损。除识别损坏和破损外,还可精确测定相位角、壁面损失、椭圆度、侵蚀模式和塞子滑移位移距离,以全面评估塞子性能和分区隔离情况。在对这一综合数据集进行详细分析后,通过分析每个堵塞位置的三维点云数据,对堵塞性能进行了深入评估。对高保真效果图和精确测量结果的分析表明,四种常用的堵头类型之间存在明显的性能差异。某些类型的堵塞更容易失效,导致套管完全破裂,而其他类型的堵塞则会出现严重的密封元件和套管侵蚀。根据失效类型,井上、目标和井下阶段可能受到的刺激不足或过度。在分析油井均匀性指数和射孔面积增长时,会对这些影响进行综合量化。与传统技术相比,这种高分辨率声学成像技术能够更快、更有效地直接识别和评估堵塞位置损坏和裂缝。利用收集到的综合数据,通过整合机器视觉算法和先进的成像软件,可以完成详细的激励性能评估。有了这个数据集,就可以有把握地改进完井设计,从而降低激励作业风险,提高压裂效率。
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引用次数: 0
ICD Completion Stimulation and Water Shutoff Using Inflatable Straddle Packers 使用充气式跨座式容器进行 ICD 完井刺激和关水
Pub Date : 2024-03-12 DOI: 10.2118/218345-ms
S. R. Fajardo
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. 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. 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. 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.
本研究描述了充气式跨距封隔器的部署和运行如何与实时螺旋管(CT)井下测量系统相结合,通过优化需要对多个区域进行选择性处理的干预措施来提高油井的生产率。目的是使所选产品只到达目标流入控制装置(ICD),同时隔离其他装置。可充气、可复位、可配置、CT 输送的跨式封隔器被设置为隔离部分生产 ICD 完井,并允许在一次运行中精确注入刺激和水一致性化学剂。该系统比其他选择性放置方法(如化学分流器)更加精确,在不同的配置(充气、定点和注入)下运行时,只需要少量的张力和/或设置重量。它与实时井下测量功能相结合,能够在整个作业过程中对实际井下条件做出快速反应和调整。该组件运行成功,并能在一次行程中选择性地刺激和关闭两个不同的区域,从而避免了使用多个堵塞来隔离不同的区段。实时井下测量套管接箍定位模块可以准确地将跨区段置于 ICD 端口前,而充气封隔器和流量控制模块则对完井的其他部分进行了机械隔离,以方便流体的放置。通过使用专为这一应用设计的软件,并结合能够进行更准确的作业后评估的存储记录仪工具,可以确认所有处理液都注入了目标 ICD 区段,防止渗透率较高的区段吸收处理液,并增加了避免注入用于充气封隔器的处理液的灵活性。本案例研究提出了一种将 CT 输送、遥测和机械井筒隔离工具相结合的创新方法,以提高具有挑战性配置的油井的产量。在通过全面设计确定优化执行策略的同时,该方法还能缩短作业执行时间,并以经济高效的方式使用处理化学液体。
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引用次数: 0
Unique Electric Line Deployed Mechanical Cutting, Milling and Pulling Solution Successfully Applied in a Complex Fishing Operation, Regaining Access to a Critical Well 独特的电力线部署机械切割、铣削和牵引解决方案成功应用于复杂的捕鱼作业,恢复了对关键油井的进入权
Pub Date : 2024-03-12 DOI: 10.2118/218329-ms
S. Murchie, O. E. Magnussen, Tore Finnesand, Kristian Andersen, Peter Gaballa
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. 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. 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.
在挪威大陆架的一个作业油田中,有一口海上注水井用于安全倾倒旧钻井水和油井碎屑,这是支持油田作业的重要资源。在对油井井下安全阀(DHSV)的功能进行例行检查时,它未能通过密封测试。为尝试解决这一问题,使用了一个流量管练习工具,但该工具继续卡在 DHSV 中,阻碍了阀门的功能,堵塞了进入油井的通道,因此在找到解决方案之前,油井无法使用。客户使用了所有常用的方法来捞出该工具,但多次使用滑绳和电子线来捞出该鱼都没有成功。此外,还使用了各种高强度捕鱼工具,包括一个高强度冲杆,可提供高达 100 Klbs 的冲力。这也没有成功,证明蛮力不是解决办法。我们对情况进行了详细分析,以确定可能的原因、所面临挑战的程度以及可供选择的适当解决方案。然后,根据需要执行的一系列关键步骤和流程,制定了一个全面的恢复计划,并创建了一个决策树,以帮助业务取得进展。步骤包括确定演习工具核心的确切位置。此外,还设计并测试了定制工具,用于固定、切割和铣削演习工具的多个内部组件,以便将其从阀门中拉出。这些 e-line 部署的解决方案极具创新性,提供了极为有效、精确和可控的能力,从而收回了流量管练习工具,进而使进一步的干预操作和随后的重新完工得以进行。由于设计了从这口井回收被卡住的演习工具的流程和解决方案,作业者设计了一种使用冲程器安全演习 DHSV 流量管的新方法,并将其作为一种替代方法加以应用。
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引用次数: 0
Restoring Production Via Non-Rig Deployed Wireline Technology 通过非钻机部署的有线技术恢复生产
Pub Date : 2024-03-12 DOI: 10.2118/218362-ms
W. J. Diwaku, H. Sambo, J. M. Sonhi, A. A. Saadi, M. Wallach
Objectives/Scope: This paper details the challenges faced and the solutions deployed to restore production following failure of a formation isolation valve (FIV). 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. 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. 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. This paper also highlights the novel technologies utilized, the milling BHA configuration, specific lessons learned, and best practices recorded during the execution.
目标/范围:本文详细介绍了地层隔离阀 (FIV) 故障后恢复生产所面临的挑战和采用的解决方案。方法、程序、过程:在部署上部完井期间,安装了 FIV 以隔离储层。井口、井树和流线连接好后,多次尝试打开阀门以启动生产。尽管按计划进行了压力循环,但 FIV 没有打开。人们怀疑是阀门顶部的填充物/碎片阻碍了阀门的液压启动。FIV 的失灵以及相关的生产损失促使团队制定了一项补救干预计划。操作员和业务合作伙伴团队评估了多种替代方案,最终选择了一种结合滑触线和电力线拖拉机部署的解决方案。该计划包括一次漂移作业,以确定 FIV 上方的井筒状况,随后进行一次清理作业,并铣削 FIV 的铬镍铁合金球阀。由于井眼角度较大,需要使用拖拉机对铣头施加压力。结果、观察结果和结论:在使用光滑管线救助器和电动管线(EL)抽吸工具清除井筒碎片后,部署了拖拉机铣削组件,成功铣削了 FIV 球阀。成功的铣削作业使油井恢复到钻井前估计的生产水平,节省了约 3000 万美元的主要钻机工作超额成本。新颖/补充信息:本文介绍了设计最佳干预计划的过程,以及详细的规划和操作步骤。最佳工程解决方案与执行过程中的操作规范相结合,成功地使油井恢复生产,最大限度地降低了生产成本损失,同时避免了昂贵的钻机干预。本文还重点介绍了所采用的新技术、铣削 BHA 配置、具体的经验教训以及执行过程中记录的最佳实践。
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引用次数: 0
The Role and Benefits of Intervention-Based Production in the Energy Transition and the Drive to Net Zero 干预型生产在能源转型和实现净零排放中的作用和益处
Pub Date : 2024-03-12 DOI: 10.2118/218369-ms
M. Billingham
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. 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. 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. 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.
这项工作旨在量化干预相关生产所减少的二氧化碳产量。已对可能的减排量进行了简要总结(Billingham 等,2023 年)。全球都在努力减少二氧化碳的产生,以实现净零排放目标并限制全球变暖。包括石油和天然气在内的化石燃料已被证明是二氧化碳排放的主要来源,这促使人们不断向 "绿色 "能源过渡。然而,在这种情况下,世界能源需求仍在继续增长,世界人口中有相当大的比例处于能源贫困状态。以绿色为基础的新能源增长势头强劲,但仅靠这些能源无法满足世界近期的能源需求。因此,在近期和中期内,石油和天然气仍将是重要的能源来源。要保持和提高产量,有两个途径,一是钻探新井,二是减少现有油田产量的下降,理想的做法是提高采收率。业内人士指出,后一种方法能以最低的碳足迹实现最廉价的生产。提高现有基础设施的利用率可以实现这一目标,而且相关的生产成本已经被量化(Billingham 等,2023 年)。这项工作评估了与干预相关的生产技术,以量化与这种生产相关的二氧化碳减排量。这项工作首先从高层次角度评估了与敏捷干预相比基于钻机的新井增产情况,然后评估了能够实现预期结果的具体技术和方法。例如,据估计,与使用模块化钻井装置(MODU)执行相同的活动相比,使用轻型干预船(LWIV)可将相关的二氧化碳产量减少 80%。此外,还对进一步改进的机会进行了调查。运营商面临着满足全球能源需求和实现净零排放目标的挑战。基于干预的生产应成为实现这一平衡的推动力。这项工作将作为行业参考,说明干预式生产在当前能源转型期间的益处,以及为何应将其作为重点。
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引用次数: 0
Safe and Successful Restoration of Wellbore Accessibility by Wellhead Gate Valve Milling 通过井口闸阀铣削安全、成功地恢复井筒的可及性
Pub Date : 2024-03-12 DOI: 10.2118/218346-ms
K. Almulhem, M. Mubarak, A. Muhammad, A. Mansour
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. 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 -. 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? 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.
油井控制一直是油气生产工程中最重要的项目之一。井口在油井控制中起着至关重要的作用,因为它由许多阀门组成,包括主阀(MV)、冠阀(CV)和翼阀(WV)。主阀(MV)是井口较低的阀门,直接暴露在井压之下。因此,确保阀门在功能测试和润滑脂方面保持稳定非常重要。通过卡在部分关闭位置的 MV 被认为是一个巨大的挑战,不仅在油井完整性方面,在油井干预方面也是如此。阀门既不能打开以进行油井干预,也不能完全关闭以承受油井压力,从而充当符合 API 标准的表面屏障。这一挑战为利用闸阀钻井装置(GVDU)铣削中压提供了机会。本文介绍了一种解决井口树卡阀的解决方案。传统的做法是利用修井(WO)钻机或盘管(CT)铣削中压并固定油井,以更换有缺陷的中压。然而,当油井不符合最低阻隔要求且作业成本较高时,这种做法更具挑战性。新一代气动闸阀驱动装置(GVDU)已经部署到位,尤其适用于铣削这种卡住/有缺陷的闸阀,而无需使用(CT)装置或有线(WL)装置。 15K 气动闸阀驱动装置已成功进行了演示,并证明其有能力铣削闸阀,以安全恢复和获得井筒可接近性。在该作业的规划阶段,考虑了多个因素以确保安全高效地执行,包括进行一系列同行评审、全面风险评估以及油井完整性和油井干预同行评审小组成员。在作业过程中,出现了一些挑战,例如在孔内运行(RIH)时压缩气体导致压力升高,通过改装放气针解决了这一问题。此外,由于 MV 处于卡死位置,杀井工作也面临挑战。因此,通过抽水增加了一条循环路径。尽管如此,使用 GVDU 有三大优势:其一是安装简单、轻便。其二是操作安全快捷,只需 2.5 个小时即可完成。第三是成本优化,除非你的想法是不涉及任何成本?这次作业的成功释放了油井在恢复井筒可接近性后的潜力。此外,它还以一种安全、超常规的快速干预、一种具有成本效益的方法、一种对环境安全和环境影响最小的方式,解决了油井完整性/控制方面的难题。
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引用次数: 0
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