气藏储层非均质性表征方法及开采物理模拟实验  

Characterization method of gas reservoir heterogeneity and physical simulation experiment of production

作　　者：胡勇[1] 贾玉泽 何东博[1] 王继平[3] 李忠诚[4] 周梦飞 魏克颖[3] 江良冀 徐轩[1] 焦春艳[1] 郭长敏[1] HU Yong;JIA Yuze;HE Dongbo;WANG Jiping;LI Zhongcheng;ZHOU Mengfei;WEI Keying;JIANG Liangji;XU Xuan;JIAO Chunyan;GUO Changmin(PetroChina Research Institute of Petroleum Exploration and Development Beijing 100083,China;University of Chinese Academy of Sciences,Beijing 100190,China;Changqing Oilfield Company,PetroChina,Xi'an 710018,China;Research Institute of Petroleum Exploration and Development,Jilin Oilfield Company,PetroChina,Songyuan 138000,China)

机构地区：[1]中国石油勘探开发研究院,北京100083 [2]中国科学院大学,北京100190 [3]中国石油长庆油田分公司,陕西西安710018 [4]中国石油吉林油田分公司勘探开发研究院,吉林松原138000

出　　处：《天然气地球科学》2022年第2期297-302,共6页Natural Gas Geoscience

基　　金：国家自然科学基金“致密砂岩微纳米孔喉系统对储层含气性及气水运移的控制机理”(编号:51704326)资助。

摘　　要：以国内砂岩气藏储层岩石为研究对象,结合高压压汞与露头踏勘及气田资料数据分析,利用孔喉半径、岩心渗透率、试井渗透率、测井渗透率等指标,建立了砂岩气藏岩石微观及储层宏观非均质表征方法,研究了岩心微观孔喉、露头剖面、区块、气田4个层级的非均质性特征。结果表明:砂岩气藏储层岩石微观孔喉结构极其复杂,渗流通道由数量众多、大小各异的各类孔隙、裂缝和喉道组成,形成一种复杂的渗流网络,无论微观上还是宏观上均表现出较强非均质性。结合储层非均质性建立全直径长岩心非均质物理模拟实验模型和方法,对比研究了高渗区布井和致密区布井2种方式的开采效果,在配产均为800 mL/min条件下,井位部署在高渗区比致密区布井的稳产期长60%,稳产期结束后产量递减快,低产周期短;高渗区布井比致密区布井的地层压力下降快,表明储量可以得到更快速动用;高渗区布井比致密区布井的采出程度上升更快,稳产期末采出程度高51.2%,采收率高14.6%。研究成果对类似气藏科学开发以及采收率提高具有指导意义。Taking the reservoir rocks of sandstone gas reservoirs in China as the research object,combined with high pressure mercury injection and outcrop reconnaissance and gas field data analysis,taking pore throat radius,core permeability,well test permeability and logging permeability as indexes,this paper established the microscopic and macroscopic heterogeneity characterization methods of sandstone gas reservoir,and studied the heterogeneity characteristics of core micro pore throat,outcrop profile,block and gas field. The results show that the microscopic pore throat structure of sandstone gas reservoir is extremely complex,and the flow channel is composed of a large number of pores,fractures and throats of different sizes,forming a complex flow network which shows strong heterogeneity both microscopically and macroscopically. Combined with reservoir heterogeneity,the physical simulation model and method of heterogeneous full-diameter long core are established,and the production effects of well distribution in high permeability area and dense area are compared and studied. Under the condition of 800 mL/min rationing production,the stable production period of well distribution in high permeability area is 60% longer than that in tight area,and the production decreases rapidly after the end of stable production period,and the low production period is short;the formation pressure of well distribution in high permeability area decreases faster than that in tight area,indicating that reserves can be used more quickly;the recovery percent in high permeability area rises faster than that in tight area,and the recovery percent at the end of stable production period is 51.2% higher while the recovery is 14.6% higher. The research results are of guiding significance for the scientific development and enhanced gas recovery of similar gas reservoirs.

关 键 词：砂岩气藏 储层非均质性 表征方法 物理模拟 提高采收率 

分 类 号：TE37[石油与天然气工程—油气田开发工程]