通过创造新的关井标准和工艺,在不损害HSE的情况下钻井新井,提高产量,案例研究-阿布扎比

I. Khalil, R. Martinez, M. Sudarev, Zainah Salem Al Agbari, A. Al-Ameri, M. Baslaib, Mohamed Ali Al-Attar, M. Albadi, Mohammed Ibrahim Al Janahi, Mohamed Salem Al-Hosani, Fouad Shamekh Al Badi
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引用次数: 0

摘要

过去在拥挤的环境中实施的陆上钻井实践已经确定,在新井的相关储层钻井之前和钻井期间,需要关闭半径2公里范围内的气井3周。这种非常保守的应急过程导致产气量显著降低,影响了目标的实现。本研究旨在确定气井的最佳排水半径,以在不牺牲安全的情况下最大限度地减少生产延迟和其他操作风险。在一个巨大的油田进行钻井活动存在许多挑战。其中一个主要挑战是在不同压力下钻井各种油藏时如何控制井筒稳定性,其中孔隙和破裂压力是设计泥浆比重的重要因素,以确保最佳的井筒稳定性;然而,在流动条件下,邻近的油井,无论是生产井还是注水井,都会影响钻井过程中意外钻井问题的严重程度,比如泥浆漏失和/或气涌,因为压力下降的附带效应会影响正在钻井的新井附近,从而影响井设计中建立的储层压力。进行了详细的研究,评估了新井钻井对周围气井排水半径的影响;考虑到衰竭或再循环油藏中发现的整个速率和渗透率范围,包括周围井的关闭时间作为一个重要的附加变量。利用单气相拟稳态径向流动方程、井底压力测量、测试数据以及之前遇到的操作问题,估算了产气井和注气井(垂直和水平)的泄放半径。同时,利用无因次半径、压力和时间来估计关井所需的稳定时间,以减少对新井的附带影响。因此,考虑到在2公里半径内钻一口井所产生的实际影响,开发了一个新的标准,以最大限度地减少气和凝析油生产的影响,评估井眼半径上的压力变化,考虑渗透率变化(100 - 30 - 1 md)和流量变化(气速:40 - 15 - 5 MMscf/d)。进行了一些敏感性和分析,最后得出了非常有趣的结论,以及新的关井选择标准,包括行动方、角色和责任以及可交付成果的流程图。新流程的目的是在作业各方之间建立通信协议,并优化周围需要关井的井数。为钻井新井制定的新井关井标准在不牺牲安全性的情况下成功实施,同时每年还节省了46.5亿立方英尺的天然气产量、260万立方英尺的凝析油和4.5亿立方英尺的注气量(即每年751万美元)。此外,新工艺可以最大限度地利用关井期进行油藏监测计划活动,并更好地规划生产/注入优化和补偿,同时为ADNOC陆上油田增加了重要的知识,并成功应用于其他具有类似挑战的地区。自豪地将该论文作为对气井关井标准的改进;设计适用于气藏类型,无论是循环或枯竭气藏模式,与最佳的钻井作业和生产过程相联系。
本文章由计算机程序翻译,如有差异,请以英文原文为准。
Production Enhancement by Creating a New Shut-in Criteria and Process for Drilling New Wells without Jeopardizing HSE, Case Study- Abu Dhabi
Onshore Drilling practices implemented in the past in congested environment had established the need to shut the surrounding gas wells within 2 km radius for time period of 3 weeks prior and during drilling of relevant reservoirs of the new well. This very conservative contingency process led to a significant reduction of gas production affecting meeting the targets. This study aims to determine the optimum drainage radius of gas wells to minimize the production deferment along with other operational risks without sacrificing safety. Drilling activities in a giant field has embedded many challenges. One of the major challenges is the one related with managing wellbore stability while drilling various reservoirs with different pressures, whereby the pore and fracture pressures are used as an important factor to design the mud weight to guarantee an optimum wellbore stability; however near-by wells either producers or injectors under flowing conditions would influence the severity of unexpected drilling issues such as mud losses and/or gas kick while drilling new wells, since the collateral effect of the pressure drawdown would affect the vicinity of the new well being drilled affecting the reservoir pressure established on the well design. A detailed study was carried out assessing the impact of the drainage radius of the surrounding gas wells while drilling a new well; considering the whole range of rates and permeability found in the depletion or recycle reservoirs including also the shut in time period of the surrounding wells as an important additional variable. The drainage radius of gas producers and injectors (vertical and horizontal) were estimated using single gas phase pseudo steady state radial flow equations and bottom hole pressure surveys test data plus operational issues previously encountered. Meanwhile, the dimensionless radius, pressure and time were used to estimate the stabilization time required shut in period to reduce the collateral effect on the new well. Accordingly, a new criterion was developed to minimize the gas and condensate production impact taking into consideration the real effect that would be created by drilling a well within the 2 Km radius, assessing pressure variation on the wellbore radius considering permeability variation (100 – 30 – 1 md) along with Flow Variation (gas rate: 40 – 15 – 5 MMscf/d). Several sensitivities and analysis were made ending with very interesting conclusions along with a new shut in well selection criteria, including flow diagram with action parties, roles and responsibilities, and deliverables. The aim of the new process is to set a communication protocol between action parties and optimizing the number of surrounding wells to be shut-in. The New Offset Wells Shut-in Criteria developed for Drilling New Wells was implemented successfully without sacrificing safety, but also saving 46.5 Bscf of gas production, 2.6 MMstb of condensate and 4.5 Bscf of gas injection per year (i.e. 751 MMUS$/year). In addition, the New Process resulted-in maximizing the utilization of the shut-in period to conduct the reservoir monitoring plan activities as well as better planning for production / injection optimization and compensation while adding an important know how effect within ADNOC Onshore being applied as a model for other areas with similar challenges successfully. Proudly present this paper as an enhancement made on the gas wells shut-in criteria; designed fit for purpose for the gas reservoir types either for recycle or depletion reservoir modes link with an optimum drilling operations and production processes.
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