渤海P油田层内生成CO<sub>2</sub>调驱技术

郑玉飞; 李翔; 徐景亮; 于萌

doi:10.11911/syztjs.2020015

渤海P油田层内生成CO₂调驱技术

中海油田服务股份有限公司油田生产事业部，天津 300459

基金项目: 国家科技重大专项课题“渤海油田高效开发示范工程”（编号：2016ZX05058-003）、中海油服科技攻关项目“SZ36-1油田层内生成CO₂调驱关键技术优化研究及应用”（编号：YSB15YF002）和“N+1轮层内生成CO₂调驱效果优化研究与应用”（编号：YSB19YF019）部分研究内容

详细信息

作者简介:
郑玉飞（1986—），男，山东日照人，2010年毕业于中国石油大学（华东）应用化学专业，2013年获中国石油大学（华东）油气田开发工程专业硕士学位，工程师，主要从事海上油田增产增注技术研究。E-mail：zhengyf4@cosl.com.cn

通讯作者:
李翔，lixiang20@cosl.com.cn

中图分类号: TE357.4
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出版历程
- 收稿日期: 2019-09-12
- 修回日期: 2019-12-11
- 网络出版日期: 2020-03-08
- 刊出日期: 2020-02-29

In-Situ CO₂Generation Technology in Bohai P Oilfield

Oilfield Production Division, China Oilfield Services Limited, Tianjin, 300459, China

摘要

摘要:
针对渤海P油田储层非均质性强、注水强度大，注入水突进和无效循环导致水驱开发效率低的问题，开展了层内生成CO₂调驱技术研究。通过生气效率评价试验优选出最优生气体系，并利用Waring-Blender法和填砂管流动试验优选了配套发泡剂和稳定剂。室内试验结果表明：最优生气体系为生气剂A+释气剂D，其生气效率可达96.2%；发泡剂体系为0.2%发泡剂2+0.1%发泡剂5，其发泡体积为740 mL，析液半衰期为219 s；发泡体系中加入稳定剂1，对渗透率2 000～10 000 mD填砂模型的封堵率在90%以上。渤海P油田15个注采井组应用了层内生成CO₂调驱技术，累计增注量69 986 m³，累计增油量33 413 m³，有效率达100%，有效期长达5个月。研究表明，层内生成CO₂调驱技术技术对渤海P油田具有良好的适用性，解决了注水开发存在的问题。
- 层内生成CO₂ /
- 调剖 /
- 生气剂 /
- 释气剂 /
- 发泡剂 /
- 实验室试验 /
- 渤海P油田
Abstract:
In order to solve the problem of low water flooding development efficiency caused by strong reservoir heterogeneity, high water injection intensity, injected water influx and ineffective circulation in the Bohai P Oilfield, a study of in-situ CO₂ generation technology was carried out. Firstly, the optimal gas generation system was selected by evaluating gas generation efficiency. Then, the foaming agent and blocking agent were screened by the Waring-Blender method and sandpack column flow experiment. Laboratory test results showed that gas generation efficiency could reach 96.2% when the gas system was blowing agent A + gas release agent D. The optimal foaming agent system was 0.2% foaming agent 2 + 0.1% foaming agent 5. The foaming volume was 740 mL and the half-life of dissolve-out liquid could be maintained for 219 seconds. When blocking agent 1 was added in the foaming system, the plugging rate could be maintained above 90% in the sandpack column with a permeability of 2 000-10 000 mD. The in-situ CO₂ generation technology had been used in 15 injector producer pairs of the Bohai P Oilfield, resulting in the enhancement of accumulative oil recovery of 33 413 m³ by injecting 69 986 m³ of CO₂ in total, with the effective rate reaching 100% and effective period up to 5 months, which indicated that in-situ CO₂ generation technology had good applicability in Bohai P Oilfield and dissolves the problems existing in the water flood development of this field.
- in-situ CO₂ generation /
- profile control /
- blowing agent /
- gas release agent /
- foaming agent /
- laboratory testing /
- Bohai P Oilfield

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图 1 层内生气试验装置

A. 水浴锅；B. 广口烧瓶；C. 酸式滴定管；D. 二口烧瓶；E. 量筒；a. 清水；b. 生气剂溶液；c. 释气剂或缓释体系

Figure 1. Experimental device of in-situ CO₂

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图 2 不同发泡剂在不同加量下的发泡体积

Figure 2. Changes of foaming volume with the concentration of different foaming agents

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图 3 不同发泡剂在不同加量下的析液半衰期

Figure 3. Changes of half-life time with the concentration of different foaming agents

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图 4 不同发泡体系的发泡体积和半衰期

Figure 4. Foam volume and half-life of different foaming systems

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图 5 泡沫加入不同稳定剂后的封堵性能

Figure 5. Comparison of plugging performance of plugging systems with different stabilizers

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表 1 不同生气体系的生气效果（60 ℃）

Table 1 Statistics of system components and gas generation effects (60℃)

生气体系	生气量/mL	理论生气量/mL	生气效率，%
生气剂A+释气剂D	279	290	96.2
生气剂B+释气剂D	280	290	96.6
生气剂C+释气剂D	279	290	96.2
生气剂A+释气剂E	242	290	83.4
生气剂B+释气剂E	249	290	85.9
生气剂C+释气剂E	267	290	92.1
生气剂A+释气剂F	66	290	22.8
生气剂B+释气剂F	78	290	26.9
生气剂C+释气剂F	123	290	42.4

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表 2 B1井层内生成CO₂注入段塞组合

Table 2 Slug formation form in-situ CO₂ generation in Well B1

注入顺序	生气剂体积/m³	隔离水体积/m³	释气剂体积/m³
段塞1	60	3	60
段塞2	60	3	60
段塞3	60	3	60
段塞4	30	3	30
段塞5	30	3	30
段塞6	30	3	30
段塞7	30	3	30

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表 3 层内生成CO₂调驱技术应用前后注水井B1井吸水剖面测试结果

Table 3 Comparison of water absorption profile in Well B1 before and after measurement of in-situ CO₂ generation

小层号	吸水量占比，%
小层号	应用前	应用后
1	25	5
2	1	9
3	69	13
4	5	73

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