石油学报 ›› 2013, Vol. 34 ›› Issue (增刊一): 29-40.DOI: 10.7623/syxb2013S1003

• 地质勘探 • 上一篇    下一篇

中国海相碳酸盐岩大气田成藏特征与模式

谢增业1,2, 魏国齐1,2, 李剑1,2, 杨威1,2, 张光武1, 国建英1,2, 张莉1,2   

  1. 1. 中国石油勘探开发研究院廊坊分院 河北廊坊 065007;
    2. 中国石油天然气集团公司天然气成藏与开发重点实验室 河北廊坊 065007
  • 收稿日期:2013-04-08 修回日期:2013-05-30 出版日期:2013-09-25 发布日期:2013-09-15
  • 通讯作者: 谢增业
  • 作者简介:谢增业,男,1965年2月生,1986年毕业于广东石油学校,2003年获中国地质大学(北京)矿产普查与勘探专业博士学位,现为中国石油勘探开发研究院廊坊分院高级工程师,主要从事油气地球化学与油气成藏综合研究工作。Email:zyxie006@126.com
  • 基金资助:

    国家重大科技专项(2011ZX05007-002);中国石油天然气集团公司天然气成藏与开发重点实验室项目资助

Reservoir characteristics and accumulation modes of large carbonate gas fields in China

XIE Zengye1,2, WEI Guoqi1,2, LI Jian1,2, YANG Wei1,2, ZHANG Guangwu1, GUO Jianying1,2, ZHANG Li1,2   

  1. 1. Langfang Branch, PetroChina Research Institute of Exploration and Development, Langfang 065007, China;
    2. CNPC Key Laboratory of Gas Reservoir Formation and Development, Langfang 065007, China
  • Received:2013-04-08 Revised:2013-05-30 Online:2013-09-25 Published:2013-09-15

摘要:

中国海相碳酸盐岩大气田主要分布在四川、塔里木和鄂尔多斯三大克拉通盆地,层系上主要富集在中下三叠统、上二叠统、石炭系、奥陶系及震旦系5大层系。截至2010年底,12个碳酸盐岩大气田储量为1.69×1012m3,占全国45个大气田储量的27.2%。碳酸盐岩大气田由单个或多个相对独立的大中型气藏组成;储层总体以低孔为主,并有随储层时代变新其孔隙度增大的趋势,单个气藏储量>10×108m3的储层平均渗透率以>1 mD为主;有效储层厚度一般为15~75 m,含气面积主要为10~100 km2;储量丰度除鄂尔多斯盆地靖边大气田为0.56×108m3/km2外,其他多>5×108m3/km2,表现为中—高丰度特征;埋藏深度范围大(1 000~6 370 m),以超深层、深层—中深层为主;气藏压力系数除磨溪气田>2.0外,其他多<1.3,主要表现为常压;由构造、岩性(含古潜山)等圈闭所组成的复合型气藏是碳酸盐岩大气田的主要气藏类型。继承性大型古隆起、多套优质烃源岩的高强度充注、断裂及侵蚀沟槽的有效输导、大面积溶蚀孔洞型空间的规模聚集、膏盐岩及泥质岩的有效封盖等要素的时空有效配置造就了碳酸盐岩天然气的规模富集与成藏。高地温场背景下的古油藏原油裂解形成干气藏、煤成气与液态烃裂解气混合形成干气藏、低地温场背景下的油藏受到干气气侵作用形成凝析气藏是碳酸盐岩大气田的三类典型成藏模式。

关键词: 碳酸盐岩, 大气田, 气藏特征, 主控因素, 成藏模式, 原油裂解气, 气侵

Abstract:

In China, large carbonate gas fields (LCGFs) are mainly distributed in three large cratonic basins, i.e., Sichuan, Tarim, and Ordos Basin. Stratigraphically, the reservoirs in these LCGFs are concentrated in five large groups of formations, including the Middle-Lower Triassic, Upper Permian, Carboniferous, Ordovician, and Sinian strata. By the end of 2010, the proven reserves of 12 LCGFs are 1.69×108m3, i.e., 27.2% of the total reserves of 45 large gas fields across the country. The LCGFs consist of single or multiple independent large-medium gas reservoirs. The formations dominantly feature low porosity which increases with old-to-new formation era. Reservoir formations with the reserves of single reservoir>10×108m3 generally have the average permeability >1 mD, net pay thickness of 15-75 m, and gas-bearing area of 10-100 km2. The reserves abundance mainly occurs at a medium-high level (>5×108m3/km2) except for that in Jingbian gas field, Ordos Basin (0.56×108m3/km2). The burial depth of reservoirs varies in a large range of 1 000-6 370 m, which is classified as super deep and deep-mid-deep. The pressure coefficient of reservoirs is generally <1.3 (i.e., normal pressure) except that in Moxi gas field (>2.0). Complex gas reservoirs formed by tectonic and lithologic traps (including buried hills) are the major reservoir type of LCGFs. Effective spatiotemporal configurations of a variety of factors, including large-scale inheriting paleo-uplift, high-intensity filling of multi-sets of quality source rocks, effective transport in fractures and erosion grooves, large-scale accumulation of dissolved pore spaces, effective seal of gypsum-salt and argillite rocks, are responsible for large-scale enrichment and accumulation of natural gas in carbonate rocks. The formation of dry gas reservoir in high geothermal field by crude oil cracking in paleo-reservoir, mixing of coal-derived and oil-cracked gases and the formation of condensate gas reservoir by gas cutting in low geothermal field are the 3 typical modes of gas accumulation in LCGFs.

Key words: carbonate reservoir, large gas field, reservoir characteristics, main controlling factor, accumulation mode, oil-cracked gas, gas cut

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