新疆石油地质

新疆石油地质 ›› 2025, Vol. 46 ›› Issue (6): 742-753.doi: 10.7657/XJPG20250610

• 油藏工程 • 上一篇    下一篇

基于地质工程一体化的井网-缝网协同优化——以准噶尔盆地吉木萨尔凹陷页岩油为例

李映艳1(), 丁艺1, 罗刚1, 丁怀宇2, 唐慧莹3(), 贺戈3   

  1. 1.中国石油 新疆油田分公司 勘探开发研究院，新疆 克拉玛依 834000
    2.中国石油 辽河油田分公司 勘探开发研究院，辽宁 盘锦 124010
    3.西南石油大学 油气藏地质及开发工程全国重点实验室，成都 610500
  • 收稿日期:2025-05-12 修回日期:2025-09-12 出版日期:2025-12-01 发布日期:2025-12-05
  • 通讯作者: 唐慧莹 E-mail:fclyy@petrochina.com.cn;anghuiying@swpu.edu.cn
  • 作者简介:李映艳（1985-），女，山东济宁人，高级工程师，硕士，非常规油气开发，（Email）fclyy@petrochina.com.cn
  • 基金资助:
    中国石油科技项目(2023ZZ15YJ03)

Collaborative Optimization of Well Pattern-Fracture Network Based on Geology-Engineering Integration Simulation：A Case Study of Shale Oil in the Jimsar Sag, Junggar Basin

LI Yingyan1(), DING Yi1, LUO Gang1, DING Huaiyu2, TANG Huiying3(), HE Ge3   

  1. 1. Research Institute of Exploration and Development, Xinjiang Oilfield Company, PetroChina, Karamay, Xinjiang 834000, China
    2. Research Institute of Exploration and Development, Liaohe Oilfield Company, PetroChina, Panjin, Liaoning 124010, China
    3. State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University, Chengdu, Sichuan 610500, China
  • Received:2025-05-12 Revised:2025-09-12 Online:2025-12-01 Published:2025-12-05
  • Contact: TANG Huiying E-mail:fclyy@petrochina.com.cn;anghuiying@swpu.edu.cn

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摘要：

准噶尔盆地吉木萨尔页岩油示范区作为首批国家级陆相页岩油示范区，目前进入规模化建产阶段，受地理位置影响，存在井位部署优化与设计方案不明确的问题。基于地质工程一体化建立可靠的地质模型，并通过数值模拟开展了井方位偏转、施工参数等优化研究，建立了可靠的一体化地质模型，建模结果表明，平台呈正断层应力特征，最小水平主应力为62~72 MPa；模拟水力裂缝长度约为微地震监测结果的85%，模拟水力裂缝高与井温监测结果相近；随井方位与最大水平主应力方向夹角减小，水力裂缝长度变长，但储层改造体积减小，受天然裂缝影响，随夹角减小，相邻段间部分裂缝在天然裂缝处合并，段间裂缝重复改造比例和非均匀差异程度上升，提示对于夹角小的井，可适当放宽压裂段长或降低单段簇数。研究认为，平台井方位偏转角度不大于60°，合理井距为200~300 m；井方位偏转大于60°后，合理井距降低，表明井方位偏转后可适当降低井距以维持较高的采收率。

关键词: 准噶尔盆地, 吉木萨尔凹陷, 页岩油, 国家级陆相页岩油示范区, 地质工程一体化, 井方位偏转, 井网-缝网优化

Abstract:

The Jimsar Shale Oil Demonstration Area in the Junggar Basin, one of the first national continental shale oil demonstration areas in China, has entered the stage of large-scale production. Due to geographical constraints, the well placement optimization and design are indefinite. A reliable geological model is established based on the geology-engineering integration and deviation of well azimuth and operation parameters are optimized through numerical simulation. The results indicate that the platform exhibits characteristics of normal-fault stress, with the minimum horizontal principal stress of 62-72 MPa. The simulated hydraulic fracture length is about 85% of the microseismic monitoring results, and the simulated hydraulic fracture height is similar to the wellbore temperature monitoring results. As the angle between the well azimuth and the maximum horizontal principal stress direction decreases, the hydraulic fracture length increases, while the stimulated reservoir volume (SRV) decreases. Some hydraulic fractures in adjacent sections merge at the part where natural fractures are present, and the proportion of repeated stimulation and degree of heterogeneity of such fractures increase. This suggests that for wells with small angle, the fracturing section length can be extended or the number of clusters in a single section be reduced properly. It is recommended that the optimal well spacing be 200-300 m when the deviation of well azimuth does not exceed 60°, and the optimal well spacing be decreased to maintain a high oil recovery when the well azimuth deviates greater than 60°.

Key words: Junggar Basin, Jimsar sag, shale oil, national continental shale oil demonstration area, geology-engineering integration, deviation of well azimuth, well pattern-fracture network optimization

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