马来西亚成熟海上油田储层变质:H2S的根本原因、缓解和管理

A. H. Mithani, E. A. Rosland, M. Jamaludin, W. R. W Ismail, Maxwell Tommie Lajawi, I. H. A Salam
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摘要

所研究的油田是一个成熟的棕地,在开发时流体流中没有H2S (PVT)。然而,最近记录到的浓度超过1000ppm,导致油井关闭(少数已经关闭)。因此,必须将关井投入生产,并完成对油田酸化潜力的评估。本文将分享我们在储井设施建模、历史拟合和预测H2S方面的经验。我们将重点介绍通过采样和建模方法找到酸化根源的工作流程,因为H2S是在整个油田的所有油藏中测量的,包括那些正在进行注水的油藏。此外,还将讨论通过模拟研究的各种备选方案,以缓解和管理该油田的H2S,以保障生产,从而实现油田的恢复。采用系统的分阶段方法来减轻和管理不需要的酸性气体(H2S)。在第一阶段,我们对整个油田H2S的历史发展进行了分析,并提出了可能导致酸化的概念。在第二阶段,我们设计并实施了端到端的全面采样和实验室分析方案,以填补现有的知识空白。在第三阶段,我们进行了三维动态储层酸化建模,对H2S进行了历史匹配,并通过预测评估了未来的潜力。最后,我们开发了多种缓解方案,包括硝酸盐注入,硫酸盐还原装置,通过水混合限制微生物生长的营养供应等。结果表明:a)注入水量的增加导致了酸化井的形成;b)酸化井与养分有效性之间存在联系;c)随着H2S浓度的增加,硫同位素的负分馏增加;d)在一些酸化井中检测到中温性srb。这一证据表明BSR是发酸的主要原因。通过水化学分析发现,注入水富含硫酸盐,地层水富含挥发性脂肪酸。结果表明,单独注入硝酸盐(高达200ppm)可能不是缓解该油田H2S的有吸引力的选择。然而,SRU和150ppm的硝酸盐注入组合在技术上是一种可行的选择,可以在允许的H2S限制范围内缓解高浓度的H2S。
本文章由计算机程序翻译,如有差异,请以英文原文为准。
Reservoir Souring in Mature Offshore Field Malaysia: Root Cause, Mitigation, and Management of H2S
The field under study is a mature brownfield with no H2S in the fluid stream (PVT) at the time of development. However, concentrations more than 1000 ppm were recorded recently causing wells to close in (few already closed). Hence, the shut-in wells have to be brought on stream and an assessment of souring potential in the field has to be completed. This paper will share our experience in H2S mapping at reservoir-well-facilities modelling, history matching and prediction of H2S. We will highlight the workflow adopted to find the root causes of souring via sampling and modelling approach since the H2S is measured throughout the field across all the reservoirs, including those undergoing waterflood. Moreover, various options that were studied through simulation will be discussed for mitigation and management of H2S within this field to safeguard the production, and thus recovery of the field. A systematic phased approach is adopted to mitigate and manage the unwanted sour gas (H2S). In first phase we performed the analysis on the historical development of H2S throughout the field and developed the concept for possible souring causes. In second phase, we designed and conducted a comprehensive sampling and laboratory analysis program end-to-end to fill the existence knowledge gap. In third phase, we performed 3D dynamic reservoir souring modelling where we history matched the H2S and assessed the future potential via forecasting. Finally, we developed multiple mitigation scenarios ranging from nitrate injection, sulphate reducing unit, limiting the nutrient supply for microbe growth via water mixing etc. It was evident that a) increased injection water contributed to souring wells, b) link between souring wells and nutrient availability, c) increased negative fractioning of Sulphur isotope as H2S concentration increases, d) and mesophilic SRBs detected in some souring wells. This evidence suggested that BSR is the predominant cause of souring. It was also seen based on water chemistry that injection water was rich in sulphate while formation water rich in volatile fatty acids. Results indicate that the nitrate injection (up to 200ppm) alone may not be an attractive option to mitigate the H2S within this field. However, the combination of SRU and nitrate injection of 150ppm could be a technically feasible options to mitigate such higher concentration of H2S within allowable facilities limits of H2S.
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