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Transient fluid flow in the Binbei district of the Songliao Basin, China Evidence from apatite fission track thermochronology

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Petroleum Science 2013年第3期10卷 314-326页

作者： xiang caifu Martin Daniík Feng Zihui State Key Laboratory for Petroleum Resource and Prospecting China University of Petroleum College of Geosciences China University of Petroleum Department of Earth & Oceanic Sciences University of Waikato Prospecting and Exploration Institute of Daqing Oil Field

The Songliao Basin is famous for the Daqing Oilfield, the biggest in China. However, no economic hydrocarbon reservoir has been found in the northeastern Binbei district. Its thermal history, which is of great importance for hydrocarbon generation and migration, is studied with apatite fission track （AFT） thermochronology. Samples with depositional ages of the late Cretaceous （-108-73 Ma） are analyzed. The AFT ages of the samples from reservoir rock （depositional age 〉 76.1 Ma） fall between the late Cretaceous （724-5 Ma） and the early Eocene （414-3 Ma） period, indicating their total annealing after deposition. In contrast, two samples from the main seals of the Qingshankou （depositional age 〉 89.3 Ma） and the Nenjiang Formation （depositional age 〉 73.0 Ma） are not annealed or partially annealed （AFT ages of 974-9 Ma and 704-4 Ma, respectively）. Because the maximum burial temperature （〈90 ℃） evidenced by low vitrinite reflectance （Ro〈0.7） is not high enough to account for the AFT total annealing （110-120 ℃）, the transient thermal effect arising from the syntectonic fluid flow between the late Cretaceous and the early Eocene is proposed. Transient thermal effects from fluid flow explains the indicated temperature discrepancies between the AFT thermometer and the Ro thermometer because the transient thermal effect from the fluid flow with a temperature high enough （110-120 ℃） to anneal the AFT thermometer does not last long enough （104-105 yrs.） for an enhancement of the Ro （minimum 106- 107 yrs. under the same temperature）. This indicates that dating thermal effect from fluid flow might be a new means to reconstruct the tectonic history. It also answers why the samples from the main seals are not annealed because the seals will prohibit fluid flow and supply good thermal insulation. The large-scale fluid flow in the Binbei district calls for a new idea to direct the hydrocarbon exploration.

关键词： Apatite fission track vitrinite reflectance transient fluid flow Binbei district Songliao Basin

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Post-Triassic thermal history of the Tazhong Uplift Zone in the Tarim Basin, Northwest China: Evidence from apatite fssion-track thermochronology

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Geoscience Frontiers 2013年第6期4卷 743-754页

作者： caifu xiang Xiongqi Pang Martin Daniík State Key Laboratory for Petroleum Resource and Prospecting China University of Petroleum College of Geosciences China University of Petroleum John De Laeter Center of Mass Spectrometry Applied GeologyCurtin UniversityPerth 6152Australia Department of Earth and Ocean Sciences The University of WaikatoPrivate Bag 3105Hamilton 3240New Zealand

The Tarim Basin is a representative example of the basins developed in the northwest China that are characterized by multiple stages of heating and *** order to better understand its complex thermal history,apatite fission track （AFT） thermochronology was applied to borehole samples from the Tazhong Uplift Zone （TUZ）.Twelve sedimentary samples of Silurian to Triassic depositional ages were analyzed from depths coinciding with the apatite partial annealing zone （～60-120 ℃）.The AFT ages,ranging from 132 ± 7 Ma （from a Triassic sample） to 25 ± 2 Ma （from a Carboniferous sample）,are clearly younger than their depositional ages and demonstrate a total resetting of the AFT thermometer after *** AFT ages vary among different tectonic belts and decrease from the *** Faulted Zone （133-105 Ma） in the northwest,the Central Horst Zone in the middle （108-37 Ma）,to the East Buried Hill Zone in the south （51 25 Ma）.Given the low magnitude of post-Triassic burial heating evidenced by low vitrinite reflectance values （Ro ＜ 0.7％）,the total resetting of the AFT system is speculated to result from the hot fluid flow along the *** effects along the faults are well documented by younger AFT ages and unimodal single grain age distributions in the vicinity of the ***-early Triassic basaltic volcanism may be responsible for the early Triassic total annealing of those samples lacking connectivity with the *** above arguments are supported by thermal modeling results.

关键词： Apatite fission track Thermochronology Tectonics Fluid flow Tazhong Uplift Zone Tarim Basin

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Formation Water Geochemistry and Its Controlling Factors: Case Study on Shiwu Rifted Sub-basin of Songliao Basin, NE China

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Petroleum Science 2006年第2期3卷 14-21页

作者： xiang caifu Lu Youmin Basin and Reservoir Research Center China University of Petroleum Beijing 102249 China Key Laboratory for Hydrocarbon Accumulation Mechanism of Ministry of Education China University of Petroleum Beijing 102249 China Marine Oil Production Plant of Shengli Oil Field Dongying Shandong 257237 China

A common way to trace fluid flow and hydrocarbon accumulation is by studying the geochemistry of formation water. This paper focuses on the spacial distribution of the geochemical features of the formation water in the Shiwu Rifled Basin and its indication of the water-rock interaction processes. The hydrodynamic field controls the spacial distribution of formation water. Due to the penetration of meteoric water, the salinity is below 4,500mg/L at the basin margin and the severely faulted central ridge and increases basin ward to 7,000-10,000mg/L. The vertical change of formation water can be divided into 3 zones, which correspond respectively to the free replacement zone （〈1,250m）, the obstructed replacement zone （1,250m-1,650m） and the lagged zone （〉 1,650m） in hydrodynamics. In the free replacement zone, the formation water is NaHCO3-type with its salinity increased to 10,000mg/L. The formation water in the obstructed replacement zone is Na2SO4-type with its salinity decreased to 5,000mg/L-7,000mg/L because of the dehydration of mud rocks. The formation water in the lagged zone is CaC12-type, but its salinity decreases sharply at a depth of 1,650m and then increases vertically downward to 10,000mg/L. This phenomenon can be best explained by the osmosis effect rather than the dehydration of mud rocks. The relationships between Cl^--HCO3^- and Na^＋＋K^＋-Ca^2＋ show that the initial water-rock interaction is the dissolution of NaCl and calcium-beating carbonate, causing an increase of Na^＋-K^＋-Ca^2＋-Cl^- and salinity. The succeeding water-rock interaction is albitization, which leads to a decrease of Na^＋ and an increase of Ca2＋ simultaneously, and generates CaCl2-type fluid. The above analysis shows that the geochemical evolution of formation water is governed by the water-rock interactions, while its spacial distribution is controlled by the hydrological conditions. The water-rock interaction processes are supported by other geological observations, suggesting that

关键词： Geochemistry of formation water hydrodynamic fields fluid-rock interaction Shiwu Rifted Basin Songliao Basin

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Dynamic Field Division of Hydrocarbon Migration,Accumulation and Hydrocarbon Enrichment Rules in Sedimentary Basins

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Acta Geologica Sinica(English Edition) 2012年第6期86卷 1559-1592页

作者： PANG Xiongqi LIU Keyu MA Zhongzhen JIANG Zhenxue xiang caifu HUO Zhipeng PANG Hong CHEN Junqing State Key Laboratory of Petroleum Resources and Prospecting China University of Petroleum Basin and Reservoir Research Center School of Natural Resources and Information TechnologyChina University of Petroleum PetroChina Research Institute of Petroleum Exploration & Development CSIRO Earth Science and Resource Engineering

Hydrocarbon distribution rules in the deep and shallow parts of sedimentary basins are considerably different, particularly in the following four aspects. First, the critical porosity for hydrocarbon migration is much lower in the deep parts of basins： at a depth of 7000 m, hydrocarbons can accumulate only in rocks with porosity less than 5%. However, in the shallow parts of basins （i.e., depths of around 1000 m）, hydrocarbon can accumulate in rocks only when porosity is over 20%. Second, hydrocarbon reservoirs tend to exhibit negative pressures after hydrocarbon accumulation at depth, with a pressure coefficient less than 0.7. However, hydrocarbon reservoirs at shallow depths tend to exhibit high pressure after hydrocarbon accumulation. Third, deep reservoirs tend to exhibit characteristics of oil （-gas）-water inversion, indicating that the oil （gas） accumulated under the water. However, the oil （gas） tends to accumulate over water in shallow reservoirs. Fourth, continuous unconventional tight hydrocarbon reservoirs are distributed widely in deep reservoirs, where the buoyancy force is not the primary dynamic force and the caprock is not involved during the process of hydrocarbon accumulation. Conversely, the majority of hydrocarbons in shallow regions accumulate in traps with complex structures. The results of this study indicate that two dynamic boundary conditions are primarily responsible for the above phenomena： a lower limit to the buoyancy force and the lower limit of hydrocarbon accumulation overall, corresponding to about 10%-12% porosity and irreducible water saturation of 100%, respectively. These two dynamic boundary conditions were used to divide sedimentary basins into three different dynamic fields of hydrocarbon accumulation： the free fluid dynamic field, limit fluid dynamic field, and restrain fluid dynamic field. The free fluid dynamic field is located between the surface and the lower limit of the buoyancy force, such that hydrocarbons in this fi

关键词： petroliferous basins dynamic force of hydrocarbon accumulation dynamic fields ofhydrocarbon accumulation hydrocarbon accumulation mechanism hydrocarbon distribution rule

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Thermochemical Sulfate Reduction in the Tazhong District,Tarim Basin,Northeast China:Evidence from Formation Water and Natural Gas Geochemistry

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Acta Geologica Sinica(English Edition) 2010年第2期84卷 358-369页

作者： xiang caifu PANG Xiongqi WANG Jianzhong LI Qiming WANG Hongping ZHOU Changqian YANG Haijun State Key Laboratory for Petroleum Resource and Prospecting China University of Petroleum Beijing 102249 China Basin and Reservoir Research Center China University of Petroleum Beijing 102249 China Tarim Oil and Gas Field SINOPEC Korla 841000 China The Exploration ＆ Production Research Institute SINOPEC Beijing 100083 China

Systematic analyses of the formation water and natural gas geochemistry in the Central Uplift of the Tarim Basin （CUTB） show that gas invasion at the late stage is accompanied by an increase of the contents of HeS and CO2 in natural gas, by the forming of the high total dissolved solids formation water, by an increase of the content of HCO3^-, relative to Cl^-, by an increase of the 2nd family ions （Ca^2＋, Mg^2＋, Sr^2＋ and Ba^2＋） and by a decrease of the content of SO4^2-, relative to Cl^-. The above phenomena can be explained only by way of thermochemicai sulfate reduction （TSR）. TSR often occurs in the transition zone of oil and water and is often described in the following reaction formula： ∑CH＋CaSO4＋H-2O→H2S＋CO2＋CaCO3. （1） Dissolved SO4^2- in the formation water is consumed in the above reaction, when HeS and CO2 are generated, resulting in a decrease of SO4^2- in the formation water and an increase of both HeS and CO2 in the natural gas. If formation water exists, the generated CO2 will go on reacting with the carbonate to form bicarbonate, which can be dissolved in the formation water, thus resulting in the enrichment of Ca^2＋ and HCO3^-. The above reaction can be described by the following equation： CO2＋HeO＋CaCO3→Ca^2＋＋2HCO3^-. The stratigraphic temperatures of the Cambrian and lower Ordovician in CUTB exceeded 120℃, which is the minimum for TSR to occur. At the same time, dolomitization, which might be a direct result of TSR, has been found in both the Cambrian and the lower Ordovician. The above evidence indicates that TSR is in an active reaction, providing a novel way to reevaluate the exploration potentials of natural gas in this district.

关键词： thermochemical sulfate reduction formation water chemistry natural gas geochemistry Central Uplift of Tarim Basin

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Ordovician Carbonate Reservoir Bed Characteristics and Reservoir-Forming Conditions in the Lungudong Region of the Tarim Basin

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Acta Geologica Sinica(English Edition) 2010年第5期84卷 1170-1179页

作者： GU Qiaoyuan PANG Xiongqi LIU Luofu YANG Haijun WANG Ying JIANG Zhenxue xiang caifu HAN Jianfa State Key Laboratory of Oil and Gas Resource and Prospecting China University of Petroleum Changping Beijing 102249 China Basin and Reservoir Research Center China University of Petroleum （Beijing） Changping Beijing 102249 China PetroChina Tarim Oilfield Company Kuala Xinjiang 841000 China

Basic characteristics of Ordovician carbonate reservoir beds in the Lungudong region of northeastern part of the Tarim Basin are described in detail and the reservoir-forming conditions of oil and gas are preliminarily discussed in this paper by collecting and sorting out a large amount of data. The carbonate reservoir beds are mainly developed in open-platform and platform marginal facies; the reservoir beds have large changes in and low average values of physical property; the main type is fractured reservoir beds with the fracture-porous type second. The reservoir bed development is chiefly controlled by the distribution of sedimentary facies, tectonic activity and karstification. Whereas the accumulation and distribution of hydrocarbons in the region are controlled by an advantageous structural location, a good reservoir-caprock combination and a favorable transporting system, with the distribution characterized by zones horizontally and belts vertically, the oil and gas are mainly concentrated in areas with structural uplift, densely developed fractures, and surface karst, a vertical vadose zone, and a horizontal undercurrent belt of palaeokarst.

关键词： Ordovician carbonates oil and gas reservoir facies Lungudong Tarim Basin Xinjiangprovince

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Characteristics of petroleum accumulation in syncline of the Songliao basin and discussion on its accumulation mechanism

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Science China Earth Sciences 2007年第5期50卷 702-709页

作者： WU HeYong LIANG XiaoDong xiang caifu WANG YueWen Daqing Oil Field Exploration and Development Research Institute Daqing 163712China Institute of Geology and Geophysics Chinese Academy of SciencesBeijing 100029China Basin&Reservoir Research Center of China University of Petroleum Beijing 102249China

The relation between oil and water in reservoirs with low and ultra-low permeability is very complicated. Gravitational separation of oil and water is not obvious. Normal reservoirs are located in depression and structural high spot, oil and water transitions are located in their middle. Stagnation is the key fact of oil-forming reservoir in the axis of a syncline based on the research of oil, gas and water migration manner, dynamics and non-Darcy flow in the Songliao basin. In low and ultra-low permeable reservoir, gas and water migrate easily through pore throats because their molecules are generally smaller than the pore throats; but the minimum diameter of oil droplets is larger than pore throats and they must be deformed to go through. Thus, gas and water migrate in advance of oil, and oil droplets remain behind. Pressure differential and the buoyancy force in a syncline reservoir are a main fluid driving force; and capillary force is the main resistance to flow. When the dynamics force is less than resistance, oil is immobile. When the buoyancy force is less than the capillary force, a gravitational separation of oil and water does not occur. The reservoir in the mature source rock of a syncline area with the low and ul- tra-low permeability belongs to an unconventional petroleum reservoir.

关键词： oil droplet pore throat syncline oil reservoir low to ultra-low permeable reservoir stagnation non-Darcy flow

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Hydrocarbon enrichment characteristics and difference analysis in the TZ1-TZ4 well block of the Tarim Basin

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Petroleum Science 2010年第2期7卷 201-210页

作者： Jiang Zhenxue Pang Xiongqi Yang Haijun Li Zhuo xiang caifu Gu Qiaoyuan State Key Laboratory of Petroleum Resources and Prospecting Beijing 102249 China Basin and ReservoirResearch Center China University＂ of Petroleum Beijing 102249 China Exploration and Development Institute of the Tarim Oilfield Company PetroChina Korla Xinjiang 841000 China

The reservoirs in the TZ1-TZ4 well block of the Tarim Basin are complex, and the hydrocarbon enrichment shows differences. The three Carboniferous oil layers are characterized by ＂oil in the upper and lower layers and gas in the middle＂ in profile and ＂oil in the west and gas in the east＂ in plane view. In order to discuss the complex reservoir accumulation mechanisms, based on the petroleum geology and reservoir distribution, we studied the generation history of source rocks, the fault evolution and sealing, the accumulation periods and gas washing, and reconstructed the accumulation process of the TZ1-TZ4 well block. It is concluded that the hydrocarbon enrichment differences of oil layers CIII, CII and CI were caused by multiple sources and multi-period hydrocarbon charging and adjustment. The CII was closely related to CIII, but CI was formed by reservoir adjustment during the Yanshan period and was not affected by gas washing after it was formed. During the Himalayan period, different degrees of gas washing in the east and west led to hydrocarbon enrichment differences on the plane. The Carboniferous accumulation process of two-stage charging and one-stage adjustment is summarized： oil charging during the late Hercynian period is the first accumulation period of CIII and CII; oil reservoirs were adjusted into CI in the Yanshan period; finally gas washing in the Himalayan period is the second accumulation period of CIII and CII, but CI was not affected by gas washing. This complex accumulation process leads to the hydrocarbon enrichment differences in the TZ1-TZ4 well block.

关键词： Tarim Basin enrichment difference multi-source and multi-period charging accumulation process

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Main progress and problems in research on Ordovician hydrocarbon accumulation in the Tarim Basin

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Petroleum Science 2010年第2期7卷 147-163页

作者： Pang Xiongqi Tian Jun Pang Hong xiang caifu Jiang Zhenxue Li Sumei Basin and Reservoir Research Center School of Natural Resources and Information Technology China University ofPetroleum Beijing 102249 China State Key Laboratory of Petroleum Resources and Prospecting China University of Petroleum Beijing 102249 China PetroChina Tarim Oilfield Company Korla Xinjiang 841000 China

The Tarim Basin is the largest petroliferous basin in the northwest of China, and is composed of a Paleozoic marine craton basin and a Meso-Cenozoic continental foreland basin. It is of great significance in exploration of Ordovician. In over 50 years of exploration, oil and gas totaling over 1.6 billion tonnes oil-equivalent has been discovered in the Ordovician carbonate formation. The accumulation mechanisms and distribution rules are quite complicated because of the burial depth more than 3,500 m, multi-source, and multi-stage accumulation, adjustment, reconstruction and re-enrichment in Ordovician. In this paper, we summarized four major advances in the hydrocarbon accumulation mechanisms of Ordovician carbonate reservoirs. First, oil came from Cambrian and Ordovician source rocks separately and as a mixture, while natural gas was mainly cracked gas generated from the Cambrian-Lower Ordovician crude oil. Second, most hydrocarbon migrated along unconformities and faults, with different directions in different regions. Third, hydrocarbon migration and accumulation had four periods： Caledonian, early Hercynian, late Hercynian and Himalayan, and the latter two were the most important for oil and gas exploration. Fourth, hydrocarbon accumulation and evolution can be generally divided into four stages： Caledonian （the period of hydrocarbon accumulation）, early Hercynian （the period of destruction）, late Hercynian （the period of hydrocarbon reconstruction and re-accumulation）, and Himalayan （the period of hydrocarbon adjustment and re-accumulation）. Source rocks （S）, combinations of reservoir-seal （C）, paleo-uplifts （M）, structure balance belt （B） matched in the same time （T） control the hydrocarbon accumulation and distribution in the Ordovician formations. Reservoir adjustment and reconstruction can be classified into two modes of physical adjustment and variation of chemical compositions and five mechanisms. These mechanisms are occurrence displacement, biodegradat

关键词： Tarim Basin carbonate reservoirs oil and gas exploration of the Ordovician hydrocarbon accumulation mechanism hydrocarbon enrichment rule

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Advances and problems in hydrocarbon exploration in the Tazhong area, Tarim Basin

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Petroleum Science 2010年第2期7卷 164-178页

作者： Zhou Xinyuan Pang Xiongqi Li Qiming Pang Hong xiang caifu Jiang Zhenxne Li Sumei Liu Luofu Tarim Oilfield Company PetroChina Korla Xinjiang 841000 China Basin and Reservoir Research Center China University of Petroleum Beijing 102249 China State Key Laboratory of Petroleum Resources and Prospecting Beijing 102249 China

Located in the middle of the Tarim Basin, Tazhong is a typical area of compound reservoirs rich in oil and gas found in the Carboniferous, Silurian and Ordovician strata. The proved, probable and possible reserves （3P reserves） in the area amount to 5×108 tons, so it is of great significance to study the advances and problems in hydrocarbon exploration in the Tazhong area. On the basis of exploration history and analysis of scientific problems, we outline eight achievements： distribution characteristics of reservoirs, stages of reservoir formation, different sources of oil and gas and their respective contributions, the effective regional caprock and reservoir-caprock combinations dominating the vertical distribution of hydrocarbon reservoirs, the control of the Tazhong Palaeo-uplift on reservoir formation and establishing geologic models, structure balance belts influencing the reconstruction and residual potential of reservoirs after accumulation, the rules and mechanisms of fractures controlling oil and gas, and the types of favorable reservoirs and their characteristics of controlling oil and gas distribution. We further point out the main problems about the oil and gas exploration in the Tazhong area and put forward some relevant proposals.

关键词： Tarim Basin petroleum geology and exploration controlling factors of hydrocarbon accumulation rules of hydrocarbon accumulation

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