突破集成的3-1/2?油管在8-1/2?成功完成油管测试的单孔胶结管

Nurul Nadia Ezzatty Abu Bakar, M. Hod, M. A. Abitalhah, A. F. Omar, Avinash Kishore Kumar, C. Lau, Ahmad Fadhli Ismail, Adhi Naharindra, Zaidi Rahimy M Ghazali
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引用次数: 0

摘要

本文介绍了马来西亚的一口探井的成功案例,该探井在8-1/2″井眼固井中应用了3-1/2″油管的突破性集成,采用了油管杆测试(TST)的新测试概念,节省了成本和钻机时间。与传统的钻柱测试(DST)相比,油管测试(TST)概念是一种将完井和试井技术整合到一个系统中的新测试方法。通过顺利、完美的计划和执行,成功实施了固井单孔技术。通过井筒和地下团队的综合规划和合作,在马来西亚的一口边缘油藏近场勘探井中,成功地使用3-1/2″油管胶结单管进行了首次油管杆测试(TST)。在规划阶段,挑战在于确保固井设计理念适合TST应用的顺利实施,包括多次风险评估、经验教训、最佳实践审查、可行性研究和多次设计挑战。在排除WAB (Welltec环空隔离器)封隔器的情况下,在3.5″× 8.5″环空段实现良好的水泥胶结,以确保井的完整性不受损害。在执行阶段,固井作业的主要问题促使项目团队重新设计适合用途的固井泥浆,并进行了多次固井测试,以确保实现固井目标。项目团队对设计进行了优化,使用了G水泥二氧化硅混合物,该混合物已被证明可以消除流体迁移,并提供良好的抗压强度(UCS)。由于CBL/VDL与目标水泥顶部的胶结良好,因此可以为新目标提供额外的射孔区域。一些良好的实践包括良好的油管隔离、高效的预冲洗、隔离剂和水泥浆设计,具有快速的抗压强度发展、良好的驱替效率和有效的桥塞碰撞策略。阐述了单井固井作业的思路、硬件和水泥浆的设计要求以及执行过程,以节省成本和提高作业效率。通过消除井筒清理(WBCU)成本,省去了7套″储层套管或尾管、DST套件、DST油管租赁、更简单的完井附件和5天的钻机作业时间,该合作计划显著节省了成本。尽管面临着水泥问题和水泥用量的挑战,但该井取得了良好的CBL/VDL结果,并实现了100%的层间隔离,从而实现了计划的射孔和额外的目标油气层。本文介绍了在8-1/2″井眼固井中使用3-1/2″油管的规划和操作实施,以实现油管杆测试(TST)作为测试作业的新方法的可行性,从而节省了成本和钻机时间。
本文章由计算机程序翻译,如有差异,请以英文原文为准。
Breakthrough Integration of 3-1/2? Tubing in 8-1/2? Hole Cemented Monobore for Successful Tubing Stem Test TST
This paper presents the success story of an exploration well in Malaysia which exemplary applied a breakthrough integration of 3-1/2″ tubing in 8-1/2″ hole cemented monobore utilizing a new well testing concept of Tubing Stem Test (TST) to save cost and rig time. The Tubing Stem Test (TST) concept which is the new approach of testing a well that integrates both completion and well test technology into a single system compared to conventional Drill Stem Test (DST). The cemented monobore technology was successfully implemented by smooth and flawless planning and execution. A comprehensive planning and collaboration of multiple disciplines in Wells and Subsurface team had ensured a successful delivery of the first Tubing Stem Test (TST) with 3-1/2″ Tubing Cemented Monobore in a near-field exploration well targeting marginal reservoir in Malaysia. During planning stage, the challenges were to ensure that the cementing design concept suits TST application to be executed smoothly by incorporating multiple of risk assessments, lessons learnt, best practices review, feasibility studies and multiple design challenge sessions. This is to ensure that the well integrity is not jeopardized by achieving good cement bond across 3.5″ × 8.5″ annulus section with exclusion of WAB (Welltec Annular Barrier) packer. During execution stage, main concern in cementing operation pushed project team to re-design the fit-for-purpose cementing slurry and multiple cement tests were performed to ensure cementing objectives were achieved. Project team optimized the design by using G Cement Silica blend which has been proven to eliminate fluid migration and provide good compressive strength (UCS). This has allowed additional perforation zone for the new target as CBL/VDL shown good cement bonding to targeted top of cement. Some of the good practices includes good tubing standoff, efficient pre-flush, spacer & cement slurry design with fast compressive strength development, good displacement efficiency and effective plug bump strategy. The thought process, design requirement both for the hardware and cement slurry, and execution follow through of cemented monobore operation in driving for cost savings and operational efficiency will be elaborated. This collaborative initiative has resulted significant cost savings by eliminating cost of wellbore clean-up (WBCU), eliminate 7″ Casing or Liner for reservoir section, DST package, DST tubing rental, simpler completion accessories and 5 days of rig operation days. Despite facing with challenging cement issue with challenging cement batch used, well has achieved good CBL/VDL result and 100% zonal isolation which has enabled perforation of planned and additional target hydrocarbon zones. Simultaneously, formation damage risk was reduced by eliminating the time the formation is exposed to overbalance brine This paper presents the planning and operational execution of 3-1/2″ Tubing in 8-1/2″ Hole Cemented Monobore to realize the feasibility of Tubing Stem Test (TST) as new approach of well testing operation to save cost and rig time.
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