CO2 Foam Pilot in a Heterogeneous Carbonate Reservoir: Analysis and Results

Z. Alcorn, A. Graue, M. Karakas
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Abstract

A CO2 foam pilot was conducted in a heterogeneous carbonate reservoir in East Seminole Field, Permian Basin USA. The primary objective was to achieve in-depth CO2 mobility control to increase CO2 sweep efficiency and improve oil recovery in an inverted 40 acre 5-spot pattern. Foam was injected in a rapid surfactant-alternating-gas (SAG) strategy with 10 days of surfactant solution injection followed by 20 days of CO2 injection. We implemented a laboratory to field upscaling approach which included foam formulation screening, numerical modeling, and field monitoring to verify foam generation and CO2 mobility reduction. The monitoring campaign obtained baseline before the pilot and monitored reservoir response to foam injection. This included conducting baseline and pilot phase CO2 and water injection profile logs, interwell CO2 tracer tests and collecting injection bottom hole pressure data and flow rates. Transient analysis was also conducted to assess foam development at reservoir conditions. The effectiveness of foam in improving overall recovery was also evaluated. Results indicate that foam was generated and CO2 mobility was reduced during the pilot based upon higher differential pressures during the SAG cycles compared to an identical water-alternating-gas (WAG) cycle. CO2 breakthrough was also delayed with foam compared to the baseline test without foam. Injection profile logs from the foam injector showed that flow increased into unswept reservoir intervals and was diverted from a high permeability streak. The effectiveness of foam in improving the overall oil recovery revealed that the foam pilot produced 30% more oil than the pattern's projected performance without foam, despite injecting at half of the historical rate during the pilot. This work presents the complete field results and analysis from the successful implementation of CO2 foam mobility control.
非均质碳酸盐岩储层CO2泡沫先导:分析与结果
在美国二叠纪盆地East Seminole油田的非均质碳酸盐岩储层中进行了CO2泡沫试验。主要目标是实现深度二氧化碳流动性控制,以提高二氧化碳波及效率,并提高40英亩5点倒立模式的采收率。采用快速表面活性剂-气体交替(SAG)策略注入泡沫,先注入表面活性剂溶液10天,然后注入二氧化碳20天。我们实施了从实验室到现场的升级方法,包括泡沫配方筛选、数值模拟和现场监测,以验证泡沫的产生和二氧化碳迁移率的降低。监测活动在试验之前获得了基线,并监测了储层对泡沫注入的响应。这包括进行基线和先导阶段的CO2和注水剖面测井,井间CO2示踪剂测试,以及收集注入井底压力数据和流速。还进行了瞬态分析,以评估储层条件下的泡沫发育情况。泡沫在提高整体回收率方面的有效性也进行了评价。结果表明,与相同的水-气交替(WAG)循环相比,在试验过程中,基于更高的压差,SAG循环产生了泡沫,二氧化碳迁移率降低。与没有泡沫的基线测试相比,泡沫也延迟了二氧化碳的突破。泡沫喷射器的注入剖面测井显示,流向未扫井的储层,并从高渗透条纹转向。泡沫在提高整体采收率方面的有效性表明,尽管在试验期间注入的速度是历史速度的一半,但泡沫先导的产油量比没有泡沫的模式的预期产量高出30%。这项工作介绍了成功实施CO2泡沫流动性控制的完整现场结果和分析。
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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