成熟油田浅层劣质气藏经济高效开发

Muhammad Abdulhadi, Hani Mohd Said, Ahmad Uzair Zubbir, Evelyn Ling, M. Nasir, Imran Anoar, Abdul Rahman Abdul Rahim, Rohani Elias, Paul Sanchez, Rizam Sharif, Zamri Abdul Ghapor, Nurhanim Ismail, Yoong Hau Kew
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引用次数: 0

摘要

水泥封隔器方法已经成功地用于寻找和开发质量较差的小型气藏。由于天然气在满足国家需求的电力供应中发挥着关键作用,因此,获得运营天然气田的许可证通常伴随着合同义务,即提供一定的天然气容量门槛。水泥封隔器方法是一种成本更低的修井替代方法,可以使作业者以更低的成本将小型气藏货币化,从而提高天然气产能。1组储层为含油气最浅的砂层,储层质量较差,储层相对较薄。此前,Minor Group-1油藏的后套管作业需要相对昂贵的拉油管钻机修井作业来实现储层的货币化。通过实施水泥封隔器,对两口井的作业机会进行了优化,从拉油管钻机修井到非钻机作业。通过冲孔将油管与套管连通,随后将水泥通过油管泵入套管。硬化后的水泥作为屏障,满足操作要求。然后对储层进行射孔、流量测试,并以较低的成本成功实现了货币化。入井前的油管和套管完整性测试表明油管和套管完整性良好。这对于确保水泥只流入打孔油管的套管至关重要。水泥硬化后,对油管和套管进行压力测试,结果表明水泥有效地隔离了两根管柱。随后的水泥胶结测井和超声成像工具显示,在目标射孔深度上方,水泥胶结良好。这些数据表明,水泥封隔器是坚固的,储层已经准备好进行额外的射孔作业。考虑到储层的质量,决定使用最大的射孔枪对储层进行两次射孔,以确保尽可能低的表皮。射孔后,油管压力急剧增加,表明储层有压力流入。尽管如此,套管压力仍然很低,证实没有通井,因此水泥封隔器成功了。由于储层压力高,该井后来能够自然卸载,确认了储层的产能,并为其他井创造了类似的机会。此外,水泥封隔器方法还为每口井节省了600万至800万美元的成本。除了确认储层的产能外,该井的成功还为该地区提供了更多的浅层天然气套管机会。这种方法现在将成为开发顶部封隔器上方任何油气资源的首选方法。
本文章由计算机程序翻译,如有差异,请以英文原文为准。
Cost-Effective Development of Shallow and Poorer Quality Gas Reservoir in Mature Field
The Cement Packer approach has been successfully implemented to pursue and monetize minor gas reservoirs of poorer quality. Due to its critical role in power supply to meet the nation's needs, license to operate gas fields oftentimes come with contractual obligations to deliver a certain threshold of gas capacity. The cement packer method is a cheaper alternative to workovers that enables operators to build gas capacity by monetizing minor gas reservoirs at lower cost. Group 1 reservoirs are the shallowest hydrocarbon bearing sand with poorer reservoir quality and relatively thin reservoirs. The behind-casing-opportunities in Minor Group-1 reservoirs previously required a relatively costly pull-tubing rig workover to monetize the reservoir. Opportunities in two wells were optimized from pull –tubing rig workovers to a non-rig program by implementing Cement Packer applications. The tubing was punched to create tubing-casing communication and cement was subsequently pumped through the tubing and into the casing. The hardened cement then acted as a barrier to satisfy operating guidelines. The reservoir was then additionally perforated, flow tested and successfully monetized at a lower cost. Tubing and casing integrity tests prior to well entry demonstrated good tubing and casing integrity. This is critical to ensure that cement will only flow into the casing where the tubing was punched. Once the cement hardened, pressure test from the tubing and from the casing indicated that the cement has effectively isolated both tubulars. Subsequent Cement Bond Log and Ultrasonic Imaging Tool showed fair to good cement above the target perforation depth. These data supported the fact that the cement packer was solid and the reservoir was ready for additional perforation. Taking into account the reservoir quality, it was decided to perforate the reservoir twice with the biggest gun available to ensure the lowest skin possible. Post perforation, there was a sharp increase in the tubing pressure indicating pressure influx from the reservoir. Despite that, casing pressure remained low, confirming no communication and thus the success of the cement packer.The well was later able to unload naturally due to its high reservoir pressure, confirming the producibility of the reservoirs and unlocking similar opportunities in other wells. Additionally, the cement packer approach delivered tremendous cost savings between $6 – 8 mil per well. Besides confirming the reservoirs' producibility,the success also unlocked additional shallow gas behind casing opportunities in the area.This method will now be the first-choice option to monetize any hydrocarbon resources in reservoirs located above the top packer.
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