The Geological Feature and Origin of Dina 2 Large Gas Field in Kuqa Depression, Tarim Basin

详细信息   

• 责任者：Zhu GuangYou(Research Institute of Petroleum Exploration and Development ; Petrochina ; Beijing 100083 ; China) ; Yang HaiJun
• 刊名：Acta Petrologica Sinica
• 出版年：2012
• 卷期：28(8)
• 关键词：凝析气 ; condensate gas ; 库车坳陷 ; Kuqa Depression
• 页码：p.2479-2492
• 图表：illus.,6 tables,58 refs.
• 分类号：1003
• issnNo：ISSN1000-0569
• isbnNo：CN11-1922/P

摘要

line !important; FONT: 12px/15px ����,verdana; WHITE-SPACE: normal; ORPHANS: 2; FLOAT: none; LETTER-SPACING: normal; COLOR: rgb(0,0,0); WORD-SPACING: 0px; -webkit-text-size-adjust: auto; -webkit-text-stroke-width: 0px">The the Dina 2 gas field, locating in the Kuqa Depression, Tarim Basin, is the largest condensate field in China. The gas beds are the Suweiyi Formation and the Kumugeliemu Group of the Paleogene. The lithology of reservoir is siltstone and fine sandstone, with low porosity and low permeability, which is similar to tight sandstone gas. The reserve abundance is more than 1.5×10⁹line !important; FONT: 12px/15px ����,verdana; WHITE-SPACE: normal; ORPHANS: 2; FLOAT: none; LETTER-SPACING: normal; COLOR: rgb(0,0,0); WORD-SPACING: 0px; -webkit-text-size-adjust: auto; -webkit-text-stroke-width: 0px">m³line !important; FONT: 12px/15px ����,verdana; WHITE-SPACE: normal; ORPHANS: 2; FLOAT: none; LETTER-SPACING: normal; COLOR: rgb(0,0,0); WORD-SPACING: 0px; -webkit-text-size-adjust: auto; -webkit-text-stroke-width: 0px">/km²line !important; FONT: 12px/15px ����,verdana; WHITE-SPACE: normal; ORPHANS: 2; FLOAT: none; LETTER-SPACING: normal; COLOR: rgb(0,0,0); WORD-SPACING: 0px; -webkit-text-size-adjust: auto; -webkit-text-stroke-width: 0px">, and the GOR is

    

line !important; FONT: 12px/15px ����,verdana; WHITE-SPACE: normal; ORPHANS: 2; FLOAT: none; LETTER-SPACING: normal; COLOR: rgb(0,0,0); WORD-SPACING: 0px; -webkit-text-size-adjust: auto; -webkit-text-stroke-width: 0px">8100~12948m³line !important; FONT: 12px/15px ����,verdana; WHITE-SPACE: normal; ORPHANS: 2; FLOAT: none; LETTER-SPACING: normal; COLOR: rgb(0,0,0); WORD-SPACING: 0px; -webkit-text-size-adjust: auto; -webkit-text-stroke-width: 0px">/m³line !important; FONT: 12px/15px ����,verdana; WHITE-SPACE: normal; ORPHANS: 2; FLOAT: none; LETTER-SPACING: normal; COLOR: rgb(0,0,0); WORD-SPACING: 0px; -webkit-text-size-adjust: auto; -webkit-text-stroke-width: 0px"> including 60~80g/m³line !important; FONT: 12px/15px ����,verdana; WHITE-SPACE: normal; ORPHANS: 2; FLOAT: none; LETTER-SPACING: normal; COLOR: rgb(0,0,0); WORD-SPACING: 0px; -webkit-text-size-adjust: auto; -webkit-text-stroke-width: 0px"> condensate oil. The geothermal system is regular with 129~138℃ of

    

line !important; FONT: 12px/15px ����,verdana; WHITE-SPACE: normal; ORPHANS: 2; FLOAT: none; LETTER-SPACING: normal; COLOR: rgb(0,0,0); WORD-SPACING: 0px; -webkit-text-size-adjust: auto; -webkit-text-stroke-width: 0px">the formation temperature and 2.224℃/100m of geothermal gradient, while the pressure system is quite abnormal with 105~106MPa of ground pressure and 0.39MPa/100m of pressure gradient or 2.06~2.29 of the pressure ratio, showing a hyperpressure system. The major component of the natural gas is wet gas, with heavy stable carbon isotope, showing a typical coal-derived origin. The heavy stable carbon isotope and biomarkers indicate terrestrial characters of the oil. The hydrocarbon was sourced from the Jurassic coaly shale of the Yangxia Sag. The trap of the Dina 2 was formed quite late. According to data of geothermal history, burial history, evolve history and fluid inclusion, and the reservoir formation time fitted by kinetics of the gas carbon isotope, we can see that the Dina 2 condensate gas field was formed since 2.5Ma. It is a typical fast charging gas reservoir in late stage. When foreland thrusting and hyperpressure was formed, the reservoir became tight and the hydrocarbon charged into the reservoir, i.e., the process of tight the reservoir and hydrocarbon charging occurred at the same time.