| 引用本文: | 张金冬,王雪梅,谭羽非,于克成,张甜甜.低渗透气藏型储气库储层物性参数的反演分析[J].哈尔滨工业大学学报,2022,54(6):105.DOI:10.11918/202012043 |
| ZHANG Jindong,WANG Xuemei,TAN Yufei,YU Kecheng,ZHANG Tiantian.Inversion analysis of physical parameters of low-permeability underground gas storage[J].Journal of Harbin Institute of Technology,2022,54(6):105.DOI:10.11918/202012043 |
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| 低渗透气藏型储气库储层物性参数的反演分析 |
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张金冬1,2,王雪梅1,2,谭羽非1,2,于克成1,2,张甜甜1,2
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(1.哈尔滨工业大学 建筑学院,哈尔滨 150006;2.寒地城乡人居环境科学与技术工业和信息化部重点实验室(哈尔滨工业大学),哈尔滨 150090)
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| 摘要: |
| 低渗透气藏改建的地下储气库注气过程,渗透率和孔隙度随着地层压力变化显著。为更准确的模拟计算低渗透气藏地下储气库的注采过程,必须掌握储气库渗透率和孔隙度随地层压力的变化规律。首先基于地质统计学中的变差函数理论,以井点已知信息为条件,确定储层物性参数的初始分布。基于反问题理论,利用地层压力的测量值和计算值之差构造目标函数,将储层物性参数的反演识别问题转化为最优化问题。通过地层压力对孔隙度和渗透率变化率的求解,利用共轭梯度法实现了对储层物性参数的反演。通过案例证明了模型的正确性。以储气库中的某一区域为研究对象进行反演分析,结果表明:虽然渗透率和孔隙度在初始时在储层中的分布规律基本一致,但是在注气结束时各位置的渗透率和孔隙度变化率都不相同,二者之间的相关性不再一致。其中渗透率变化最大的位置出现在5#注采井附近,其值由1.66×10-3 μm2增加到2.81×10-3 μm2,增加了近70%。并利用最小二乘法拟合得到了渗透率和孔隙度与地层压力之间的函数关系式。本研究成果可以为低渗透气藏改建地下储气库的注采模拟提供理论依据。 |
| 关键词: 气藏型储气库 低渗透 渗透率 孔隙度 地层压力 反演分析 |
| DOI：10.11918/202012043 |
| 分类号:TE822 |
| 文献标识码:A |
| 基金项目:十三五重点研发项目(2018YFC0809903) |
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| Inversion analysis of physical parameters of low-permeability underground gas storage |
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ZHANG Jindong1,2,WANG Xuemei1,2,TAN Yufei1,2,YU Kecheng1,2,ZHANG Tiantian1,2
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(1.School of Architecture,Harbin Institute of Technology, Harbin 150006, China;2.Key Laboratory of Cold Region Urban and Rural Human Settlement Environment Science and Technology (Harbin Institute of Technology), Ministry of Industry and Information Technology, Harbin 150090, China)
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| Abstract: |
| The permeability and porosity vary significantly with different formation pressure in the gas injection process of the underground gas storage reconstructed from low-permeability gas reservoirs. It is necessary to understand the variation of permeability and porosity with formation pressure so as to simulate the injection and production process of underground gas storage. Firstly, the variogram theory in geostatistics was introduced, and the initial distribution of the reservoir physical parameters was determined based on the known information of the well points. Next, on the basis of the inverse problem theory, the differences between the measured values and calculated values of formation pressure were used to construct objective function, thereby transforming the inversion identification problem of reservoir physical parameters into the optimization problem. Then, the change rate of formation pressure to porosity and permeability was solved, and the physical parameters of reservoir were inversed by using conjugate gradient method. The correctness of the model was proved by a case study. A certain area of gas storage was taken as the research object for inversion analysis. Results show that although the distribution of permeability and porosity in the reservoir was basically the same at the beginning, the change rate of permeability and porosity was different at the end of gas injection, and the correlation between them was not consistent. The biggest change in permeability occurred near the 5# injection production well, and the value increased from 1.66×10-3 μm2 to 2.81×10-3 μm2, with an increase of nearly 70%. The function relationship between permeability, porosity, and formation pressure was built with the least square method. The research results can provide a theoretical basis for the injection and production simulation of low-permeability gas reservoirs converted to underground gas storage. |
| Key words: underground gas storage of gas reservoir type low permeability permeability porosity formation pressure inversion analysis |
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