缅甸近海严重受损富粘土砂岩储层砾石充填完井的创新酸化解决方案

DongKyoon Kim, Y. Bae, Hai Liu
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引用次数: 0

摘要

在含有大量粘土的砂岩储层中,由于酸化液与地层粘土之间发生了意想不到的反应,酸化可能会导致意想不到的结果。本文展示了缅甸近海严重受损的富粘土砂岩储层如何通过套管井砾石充填(CHGP)完井,并通过有机粘土酸增产处理成功建立商业生产。地层为层状脏砂,粘土含量非常高(高达30%),总高度很大(>100m MD)。生产测井结果显示,只有一小部分射孔段对生产有贡献。因此,需要采取适当的增产措施来释放井的潜力,防止小井段集中流动导致筛管失效。考虑到粘土含量高以及酸敏感粘土的存在,使用HCl作为预冲液和氢氟酸(HF)作为主要流体的常规处理将导致二级和三级反应的潜在损害。此外,处理后剩余的临界基质中未溶解的粘土可能会迁移并堵塞孔喉。新酸体系的设计目的是在任何给定时间生成少量的原位HF(~ 0.1%),总强度为1% HF,这将大大减少二次和三级反应,并允许酸深入地层。此外,反应产物会与粘土发生反应,将未溶解的粘土永久地“焊接”到孔隙空间表面,并阻止其迁移。该处理分为三个阶段:1)使用连续油管(CT)喷射进行筛管和砾石充填清理;2)注入性测试;3)以乙酸为预冲液,以新酸体系为主要流体,再进行过冲处理。采用新设计的含相对渗透率改性剂的线性凝胶进行导流。对两口表现不佳的CHGP井进行了处理,两口井的产能都提高了100%,地面没有观察到良好的产量。该项目的成功归功于复杂的工程工作流程,从诊断损伤区域和地层损伤的根本原因开始,然后使用径向数值油藏模型对所有油藏层进行各种皮肤成分的详细分析,从而根据损伤和地层矿物学以及全面的实验室测试制定适当的处理策略和流体设计。这有助于将处理风险降至最低,并最终从严重受损的砂岩油藏中恢复生产。
本文章由计算机程序翻译,如有差异,请以英文原文为准。
Innovative Acidizing Solutions for Severely Damaged Clay-Rich Sandstone Reservoir with Gravel Pack Completions in Offshore Myanmar
Acid stimulation in sandstone reservoirs containing significant amount of clays can end up with undesired results due to unexpected reactions between stimulation fluids and formation clays. This paper demonstrates how heavily damaged clay-rich sandstone reservoir completed with cased hole gravel pack (CHGP) in offshore Myanmar can be successfully established for commercial production with organic clay acid stimulation treatment. The formation is laminated dirty sand with very high clay content (up to 30%) and large gross height (>100m MD). Production logging results showed only a small portion of perforated intervals contributing to production. Thus, an appropriate stimulation treatment is required to unlock well potential and prevent screen failures from concentrated flow through a small interval. Given high clay content as well as presence of acid sensitive clays, conventional treatments using HCl as preflush and hydrofluoric (HF) acids as main fluids would result in potential damages from secondary and tertiary reactions. Furthermore, undissolved clays in the critical matrix left over from the treatment would potentially migrate and plug the pore throat. The new acid system was designed to generate small amount of HF in-situ (∼0.1%) at any given time with total strength of 1% HF, which would greatly minimize second and tertiary reactions and also permits acids travel deeper into the formation. Furthermore, the reaction products would react with the clays and physically "welding" the undissolved clays to the surface of the pore spaces permanently and prevent them from migration. The treatment was designed in three stages: 1) screen and gravel pack cleanup using coiled tubing (CT) jetting; 2) injectivity test; 3) main treatment consisting of acetic acids as preflush, and new acid system as main fluids followed by overflush. A newly designed linear gel containing relative permeability modifier was used for diversions. Two underperforming CHGP wells were treated, and both wells yielded 100% increase in productivity with no fine production observed at the surface. The success of the campaign owes to the sophisticated engineering workflow which starts from diagnostic of the damage zone and root-cause of the formation damage, followed by detailed analysis of various skin components using radial numerical reservoir modeling for all the reservoir layers that led to a proper treatment strategy and fluid design based on the damage and formation mineralogy as well as comprehensive laboratory tests. This has helped to minimize the risk of the treatment and eventually unlocked the production from the heavily damaged sandstone reservoir.
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