动态缩放预测模型及在超深层天然气储层近井筒形成中的应用

IF 3.2 3区 工程技术 Q1 ENGINEERING, PETROLEUM
SPE Journal Pub Date : 2024-02-28 DOI:10.2118/219471-pa
Lihu Cao, Hua Yuan, Zhaocai Pan, Zhibin Liu, Bao Zhang, Tao Sun, Jianyi Liu, Hongjun Wu
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引用次数: 0

摘要

超深层天然气储层具有高温和高盐度的特点,为解决其近井筒地层内的重大缩放难题,我们开发了一种动态缩放预测模型。该模型专门用于预测裂缝基质双孔隙储层中气水两相渗流的缩放情况。它考虑了水蒸发对地层水离子产生的浓度效应。我们的缩放模型采用有限体积法进行离散求解。我们还对气井进行了现场动态缩放模拟,从而可以精确预测储层中离子浓度的分布、孔隙度和渗透率特性的变化以及缩放规律的动态变化。模拟结果显示,地层压力显著下降,在生产 7.5 年后从 105 兆帕下降到 76.7 兆帕。井筒附近地层尤其受到严重缩放的影响,这主要归因于径向压降漏斗效应,导致井筒附近缩放离子浓度降低。碳酸钙被确定为储层中最主要的结垢成分,而硫酸钙则是次要的结垢成分,二者合计约占结垢沉积总量的 85.2%。相比之下,结垢对储层内基质系统的影响仍然很小。然而,中央裂缝系统受到了明显的破坏,孔隙度降低了 71.2%,渗透率降低了 59.8%。井筒周围 5 米半径范围内的裂缝系统被认为是储层中主要的缩放破坏区域。使用本研究提出的模拟方法,可以为分析气田储层的动态缩放模式和优化缩放减缓过程提供有价值的支持。
本文章由计算机程序翻译,如有差异,请以英文原文为准。
Dynamic Scaling Prediction Model and Application in Near-Wellbore Formation of Ultradeep Natural Gas Reservoirs

To address the significant scaling challenges within the near-wellbore formation of ultradeep natural gas reservoirs characterized by high temperature and high salinity, we developed a dynamic scaling prediction model. This model is specifically designed for the prediction of scaling in gas-water two-phase seepage within fractured-matrix dual-porosity reservoirs. It accounts for the concentration effects resulting from the evaporation of water on formation water ions. Our scaling model is discretely solved using the finite volume method. We also conducted on-site dynamic scaling simulations for gas wells, allowing us to precisely predict the distribution of ion concentrations in the reservoir, as well as changes in porosity and permeability properties, and the scaling law dynamics. The simulation results reveal a significant drop in formation pressure, decreasing from 105 MPa to 76.7 MPa after 7.5 years of production. The near-wellbore formation is particularly affected by severe scaling, mainly attributed to the radial pressure drop funneling effect, leading to a reduction in scaling ion concentrations in the vicinity of the wellbore. Calcium carbonate is identified as the predominant scaling component within the reservoir, while calcium sulfate serves as a secondary contributor, together accounting for roughly 85.2% of the total scaling deposits. In contrast, the scaling impact on the matrix system within the reservoir remains minimal. However, the central fracture system exhibits notable damage, with reductions of 71.2% in porosity and 59.8% in permeability. The fracture system within a 5-m radius around the wellbore is recognized as the primary area of scaling damage in the reservoir. The use of the simulation approach proposed in this study can offer valuable support for analyzing the dynamic scaling patterns in gasfield reservoirs and optimizing scaling mitigation processes.

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来源期刊
SPE Journal
SPE Journal 工程技术-工程:石油
CiteScore
7.20
自引率
11.10%
发文量
229
审稿时长
4.5 months
期刊介绍: Covers theories and emerging concepts spanning all aspects of engineering for oil and gas exploration and production, including reservoir characterization, multiphase flow, drilling dynamics, well architecture, gas well deliverability, numerical simulation, enhanced oil recovery, CO2 sequestration, and benchmarking and performance indicators.
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