Stereoscopic Development Exploration of Shallow Shale Gas in Zhaotong National Shale Gas Demonstration Area: Case Study of YS203H1 Pad of Haiba Anticline Southern Limb
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摘要: 昭通国家级示范区浅层页岩气分布面积广、地质储量大，具备较大开发潜力.为实现示范区中部海坝背斜浅层页岩气的高效建产和资源最大化动用，在总结示范区太阳背斜浅层页岩气立体开发经验基础上，遵循地质工程一体化理念和研究思路对海坝浅层页岩气立体开发可行性及井网部署方式进行探索.结果表明：单层井网开发仍以龙一11小层为最佳靶体，五峰组在当前工艺技术和经济指标下，暂不具备作为独立开发层系经济开发的条件，仍需进一步探索；龙一11小层+龙一13小层间Ⅰ+Ⅱ类优质储层厚度大，相比龙一11单层开发，采用龙一11小层+龙一13小层下部双层立体交错井网在相同井距及井数的立体开发方案下，井组EUR及IRR均有较大增加；在相同控制面积条件下，井距和井数之间存在最优化区间，在当前工艺技术和经济指标下，建议250 m为最佳井距；若建井及改造成本下降，有进一步缩小井距、提高井组整体EUR的潜力；大规模水力压裂不但会改变就地应力大小，还会改变水平主应力方向，从而改变近井地带应力状态，使其从走滑型向逆断层状态转变，易形成水平缝导致压裂改造效果变差；采用一次井网相较于加密井网部署方案，能有效降低井间应力负面干扰，提高井间储量动用程度.海坝浅层页岩气适宜采取适度小井距立体交错一次井网部署的开发方式，以助推示范区浅层页岩气的规模效益开发.Abstract: The shallow shale gas in the Zhaotong area has a wide distribution and large geological reserves, with a large development potential. To realize the efficient production and resource utilization of shallow shale gas in the Haiba backslope of the central area, based on the experience of the Taiyang backslope, the feasibility of the stereoscopic development of shallow shale gas in Haiba and the deployment of the well pattern were explored, based on the geology-engineering integration concept and research workflow. The research result shows that the best target for single-layer development is still the Long 111 layer, and the Wufeng Formation does not have the conditions for economic development as an independent development layer system under the current process technology and economic index, and further exploration is still needed. The thickness of Class Ⅰ+Ⅱ high quality reservoir between Long 111 layer + Long 113 layer is large, compared with the development of Long 111 single layer, using Long 111 minor layer + Long 113 layer with stereoscopic staggered well pattern in the same well spacing and number of wells, the platform EUR and IRR are greatly increased. Under the same control area conditions, there is an optimal interval between well spacing and well number, and 250 m is recommended as the best well spacing under the current technology and economic index; if the well construction cost decreases, there is a potential to further reduce the well spacing and improve the overall EUR of the platform. Large-scale hydraulic fracturing will not only change the in-situ stress magnitude, but also change the horizontal principal stress direction, thus changing the stress state in the near-well zone from a walking-slip to a reverse-fault state, and adversely affecting the hydraulic fracturing due to T shape fracture. One-time well deployment can effectively reduce negative inter-well stress interference and improve the degree of inter-well reserve utilization compared to the infill well pattern deployment. In conclusion, the development of shallow shale gas in Haiba is suitable to adopt a stereoscopic staggered one-time well pattern with small well spacing, promoting the development of Zhaotong area shallow shale gas in a cost-effective way.
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图 1 海坝背斜北翼YS137（a）及南翼YS203（b）五峰‒龙马溪组地层真实厚度对比（以五峰组底部拉平）
Fig. 1. Comparison of the true thickness of the Wufeng-Longmaxi Formation in north limb YS137 (a) and south limb YS203 (b) of the Haiba anticline (flatten with the horizon of bottom of the Wufeng Formation)
图 2 YS203五峰‒龙马溪组不同起裂层位对裂缝纵向发育的影响对比
Fig. 2. Comparison of the effect of different fracture initiation layers on the longitudinal development of fractures in the Wufeng- Longmaxi Formation of YS203
图 3 YS203H1井组五峰‒龙马溪组各小层水平井生产20年累计产气量
Fig. 3. EUR of wells in each layer of the Wufeng-Longmaxi Formation of the YS203H1 pad in 20 years of production
图 4 YS203H1井组设计方案平面/剖面分布（以250 m井距单层和立体开发为例）
a、c.单层、立体开发井平面示意图；b、d.单层、立体开发井储量动用示意图
Fig. 4. YS203H1 pad design plan/section distribution (250 m well spacing single layer and stereoscopic development)
图 5 YS203H1井组9种设计方案对应裂缝参数对比
Fig. 5. 9 design options of YS203H1 corresponding to HF parameters comparison
图 6 太阳‒大寨区块已投产水平井有效裂缝长度统计
Fig. 6. Effective fracture length statistics of production horizontal wells in the Taiyang-Dazhai block
图 7 YS203H1井组生产20年后地层压力分布
Fig. 7. Formation pressure distribution in YS203H1 pad after 20 years of production
图 8 YS203H1井组9种设计方案对应EUR及IRR对比
Fig. 8. Comparison of EUR and IRR corresponding to 9 design options of YS203H1 pad
图 9 YS203H1井组一次布井与加密布井各方案(含水力裂缝)最小水平主应力示意图
Fig. 9. Schematic diagram of minimum horizontal principal stress of YS203H1 pad on one-time and infill well scenarios (with hydraulic fracture network)
图 10 YS203H1井组一次布井与加密布井方案最小水平主应力方位变化示意图
Fig. 10. Minimum horizontal principal stress orientation change diagram of YS203H1 pad on one-time and infill well scenarios
图 11 YS203H1井组一次布井与加密布井方案生产20年地层压降示意图
Fig. 11. Formation pressure distribution of YS203H1 pad on one-time and infill well scenarios
图 12 YS203H1井组一次井网部署与加密布井方案生产20年EUR对比（归一化时间）
Fig. 12. 20-year EUR comparison (normalized time) of YS203H1 pad on one-time and infill well scenarios
表 1 不同埋深页岩储层地质‒工程参数对比（据何勇等，2021修改）
Table 1. Comparison of geology-engineering parameters of shale reservoirs with different burial depths (modified from He et al., 2021)
区块 目的层埋深
(m)最小水平主应力
(MPa)上覆地层应力(MPa) 地层压
力系数Ⅰ+Ⅱ类储层厚度
(m)靶体厚度
(m)靶体钻遇率(%) 加砂强度(t/m) 单井成本
(104元)中深层HJB-108井区 2 509 56.5 61.0 2.00 50.5 7.3 94 1.6 > 5 000 浅层TY-102井区 760 16.0 18.8 1.43 32.0 1.2 72 3.0 < 2 500 浅层YS203井区 1 641 28.0 43.6 1.10~1.25 27.0 2~4 约75 3.0 约3 000 
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表 2 YS203井五峰‒龙马溪组页岩综合测井数据
Table 2. Comprehensive logging data of the Wufeng-Longmaxi Formation shale in Well YS203
层位 顶、底深
(m)层厚
(m)最小水平主应力
(MPa)水平主应力差
(MPa)地层压力系数 含气量
(m3/t)泊松比 杨氏模量
(GPa)有效孔隙度
(%)储层分类 龙一14 1 515.7~1 629.9 14.2 35.7 25.6 1.04 0.7 0.267 43.3 0.8 三类 龙一13 1 629.9~1 636.0 6.1 33.0 20.7 1.25 2.6 0.230 33.9 3.2 二类 龙一12 1 636.0~1 642.1 6.1 30.2 23.7 1.11 3.0 0.200 38.0 3.0 二类 龙一11 1 642.1~1 644.2 2.1 29.3 22.0 1.12 4.5 0.192 35.0 4.3 一类 五峰组 1 644.2~1 657.1 12.9 31.9 21.6 1.16 2.8 0.222 35.2 3.4 二类
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表 3 YS203H1井组水力压裂模拟“体积压裂2.0”工艺施工参数（据何勇等，2021修改）
Table 3. Hydraulic fracturing simulation "volume fracturing 2.0" parameters for YS203H1 pad (modified from He et al., 2021)
压裂水平段长
（m）单段长
（m）段数 簇间距
（m）单段簇数
（簇）加砂强度
（t/m）单段液量
（m3）加液强度
（m3/m）施工排量
（m3/min）1 000 80 12 15 6 3.0 2 400 30 16
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