Injection of Low-Salinity Water as an Integral Part of Enhanced Oil Recovery Programmes for Carbonate Formations of the Central-Khoreiver Uplift Oilfields

Day 1 Tue, October 12, 2021 Pub Date : 2021-10-12 DOI:10.2118/206433-ms

A. Kornilov, I. Tkachev, A. V. Fomkin, Andrey Mikhailovich Petrakov, D. Batrshin, G. Fursov, Denis Mikhailovich Ponomarenko, G. Fedorchenko, Geroge Vladimirovih Sansiev

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Abstract

The paper describes the process of evaluation of low salinity water composition to improve the development of hydrophobic carbonate formations of Central-Khoreiver Uplift (CKU) fields with relatively high oil viscosity (5-15 mPa·s) and average formation temperature 70°C. The sources of low salinity water were determined, prospective composition for water injection were analyzed. The efficiency of oil displacement by formation water and low salinity water are observed during the spontaneous imbibition experiments and coreflood tests to compare the efficiency of formation and low salinity water. The expected incremental displacement efficiency for the target carbonate formations can vary widely, from 1 to 10%. Linear models of the completed coreflood tests and a sector hydrodynamic model of the prospective trial injection are built, considering the basic chemical processes while mixing different types of water. We also review the prospects of joint application of low salinity water injection and chemical EOR methods.

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注入低矿化度水是中部霍里河隆起油田碳酸盐岩储层提高采收率的重要组成部分

本文介绍了中河隆起(central - khoreriver隆起，CKU)油田低矿化度水成分评价过程，以改善疏水碳酸盐岩地层的开发，该油田具有较高的原油粘度(5 ~ 15 mPa·s)，平均地层温度为70℃。确定了低矿化度水的来源，分析了注水前景。通过自吸实验和岩心驱油试验，观察了地层水和低矿化度水驱油效率，比较了地层水和低矿化度水驱油效率。目标碳酸盐岩地层的预期增量驱替效率变化很大，从1%到10%不等。考虑混合不同类型水的基本化学过程，建立了已完成的岩心驱油试验的线性模型和预期试注的局部水动力模型。展望了低矿化度注水与化学提高采收率联合应用的前景。

本文章由计算机程序翻译，如有差异，请以英文原文为准。

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Day 1 Tue, October 12, 2021

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