Xiaoqi Wu
Sinopec
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Featured researches published by Xiaoqi Wu.
Energy Exploration & Exploitation | 2014
Quanyou Liu; Zhijun Jin; Wenhui Liu; Xiaoqi Wu; Bo Gao; Dianwei Zhang; Anping Hu; Chun Yang
Taking the geology and tectonic evolution characteristics of the Sichuan Basin into account, the chemical and stable isotopic compositions of natural gas, and biomarker compounds in the reservoir bitumen in the Puguang giant gas field, are investigated to identify the genetic type of marine sour natural gas, take the gas-source correlation, and set up the gas-filling model of the Puguang giant gas field in the Sichuan Basin. The alkane gases in the field are dominated by methane, ranging from 22.06% to 99.64% with an average value of 76.52%, and the low content of heavy hydrocarbon gases are dominantly ethane and little propane. The H2S contents occur among the marine carbonate gas reservoirs, ranging from 0 to 62.17%, wherein the H2S contents in the Upper Permian Changxing Formation and Lower Triassic Feixianguan Formation range from 6.9% to 34.72% (average value=15.27%) and from 0% to 62.17% (average value= 13.4%), respectively, indicating that both are H2S-enriched reservoirs. The chemical and carbon isotopic compositions of marine natural gases show that the alkane gas in the Puguang giant gas field is dominantly oil-cracking gas at high maturity stage, and the biomarker characteristics of reservoir bitumen indicate that the major source rocks are the Upper Permian Longtan Formation sapropelic matters. Moreover, various levels of thermochemical sulfate reduction (TSR) were present in the process of oil-gas transformation, not only increasing the content of non-hydrocarbon gas components (CO2 and H2S) and decreasing the content of heavy hydrocarbon gases, but also causing the reversal of carbon isotope compositions of methane and ethane and the heavier carbon isotope of methane. The recovery of structural configurations over geological time investigates that the gas-filling history of Puguang giant gas field can be divided into three stages: formation of paleo-oil accumulation from the middle-late Indosinian period to the early Yanshanian period, thermal cracking of paleo-oil and TSR alteration from the early to the middle Yanshanian period, and adjustment of gas accumulation from the late Yanshanian to the early Himalayan period. The gypsum of the Lower Triassic Jianglingjiang Formation and the Middle Triassic Leikoupo Formation plays the most important role as effective seal to the gas preservation in different periods.
Energy Exploration & Exploitation | 2014
Xiaoqi Wu; Xiaowan Tao; Guoyi Hu
Plentiful natural gas has been discovered in Tazhong area in the Tarim Basin, and is mainly reservoired in Ordovician at the northern slope and in Carboniferous at the central fault horst. The analyses on natural gas components and carbon and hydrogen isotopes indicate that the natural gas in Tazhong area is mainly composed by alkanes with methane contents generally over 60%. The dryness indexes and N2 and CO2 contents are regionally different with low contents of H2S. The δ13C1 and δD1 values of alkane gas from the western part of northern slope are generally lower than −45‰ and −160‰ respectively, whereas those from the central and eastern parts are mainly higher than −45‰ and −160‰ respectively, and those from the central fault horst are mainly centralized in the ranges of −46.3‰∼−42.3‰ and −163‰∼−154‰ respectively. The alkanes display positive carbon and hydrogen isotopic series, and a few gas samples are partially reversed. The geochemical characteristics indicated that the alkane gas in Tazhong area was oil-associated and derived from the sapropelic organic matters. Natural gas from the western part of the northern slope was mainly generated in the early stage of oil cracking and was mixed by kerogen-cracking gas, and that from the central fault horst was mainly the products of oil cracking to a higher extent, whereas the gas from the central and eastern parts of the northern slope was mainly derived from the primary cracking of kerogen. The mixing analog calculation indicated that the high δ13CCO2 values was caused by the mixing of inorganic CO2 which had been generated in the dissolution reaction of reservoir carbonate rocks under acidic conditions.
Journal of Asian Earth Sciences | 2015
Quanyou Liu; Zhijun Jin; Qingqiang Meng; Xiaoqi Wu; Huichong Jia
Organic Geochemistry | 2014
Quanyou Liu; Zhijun Jin; Xiaoqi Wu; Wenhui Liu; Bo Gao; Dianwei Zhang; Jian Li; Anping Hu
Organic Geochemistry | 2014
Yunyan Ni; Jinxing Dai; Shizhen Tao; Xiaoqi Wu; Fengrong Liao; Wei Wu; Dijia Zhang
Journal of Asian Earth Sciences | 2016
Quanyou Liu; Jinxing Dai; Zhijun Jin; Jian Li; Xiaoqi Wu; Qingqiang Meng; Chun Yang; Qinghua Zhou; Zihui Feng; Dongya Zhu
Organic Geochemistry | 2014
Xiaoqi Wu; Xiaowan Tao; Guoyi Hu
Marine and Petroleum Geology | 2018
Quanyou Liu; Zhijun Jin; Huili Li; Xiaoqi Wu; Xiaowan Tao; Dongya Zhu; Qingqiang Meng
Chemical Geology | 2017
Quanyou Liu; Dongya Zhu; Zhijun Jin; Qingqiang Meng; Xiaoqi Wu; Hao Yu
Marine and Petroleum Geology | 2018
Quanyou Liu; Zhijun Jin; Xiaofeng Wang; Jizheng Yi; Qingqiang Meng; Xiaoqi Wu; Bo Gao; Nie Haikuan; Dongya Zhu