塔里木盆地下古生界烃源岩二次生烃范围研究

塔里木盆地是一个多旋回叠合盆地,下古生界烃源岩具有典型的二次生烃特征.当前关于二次生烃的研究集中在通过热模拟方法认识生烃机理和模式等方面,关于典型盆地二次生烃发生范围、分布规律、影响因素研究相对较少.本文在认识塔里木盆地构造背景和热演化规律的基础上,选取不同构造单元具有代表性的50余口井,利用Basin Mod 1D盆地模拟软件对多口井进行烃源岩成熟史模拟,结合现有的镜质体反射率数据,研究奥陶系和寒武系烃源岩是否存在二次生烃以及二次生烃发生时期和规律.综合分析单井模拟结果发现,奥陶系烃源岩二次生烃发生范围分布在沙雅隆起、卡塔克隆起中部和古城墟隆起西端,寒武系烃源岩二次生烃发生范围分布在沙雅隆起、巴楚隆起和卡塔克隆起中部.不同构造单元二次生烃开始的时间不同.二次生烃生烃史受盆地构造-热演化史控制,且对油气藏形成和分布有一定影响.     

Carbon isotopic compositions of 1,2,3,4-tetramethylbenzene in marine oil asphaltenes from the Tarim Basin: Evidence for the source formed in a strongly reducing environment

Although 1-alkyl-2,3,6-trimethylbenzenes and a high relative amount of 1,2,3,4-tetramethylbenzene have been detected in marine oils and oil asphaltenes from Tabei uplift in the Tarim Basin, their bio-logical sources are not determined. This paper deals with the molecular characteristics of typical ma-rine oil asphaltenes from Tabei and Tazhong uplift in the Tarim Basin and the stable carbon isotopic signatures of individual compounds in the pyrolysates of these asphaltenes using flash pyrolysis-gas chromatograph-mass spectrometer (PY-GC-MS) and gas chromatograph-stable isotope ratio mass spectrometer (GC-C-IRMS), respectively. Relatively abundant 1,2,3,4-tetramethylbenzene is detected in the pyrolysates of these marine oil asphaltenes from the Tarim Basin. δ 13C values of 1,2,3,4-tetrame-thylbenzene in the pyrolysates of oil asphaltenes vary from-19.6‰ to-24.0‰, while those of n-alkanes in the pyrolysates show a range from-33.2‰ to-35.1‰. The 1,2,3,4-tetramethylbenzene in the pyro-lysates of oil asphaltenes proves to be significantly enriched in 13C relative to n-alkanes in the pyro-lysates and oil asphaltenes by 10.8‰―15.2‰ and 8.4‰―13.4‰, respectively. This result indicates a contribution from photosynthetic green sulfur bacteria Chlorobiaceae to relatively abundant 1,2,3,4-tetramethylbenzene in marine oil asphaltenes from the Tarim Basin. Hence, it can be speculated that the source of most marine oil asphaltenes from the Tarim Basin was formed in a strongly reducing water body enriched in H2S under euxinic conditions.     

Geochemical characteristics and accumulation of marine oil and gas around Halahatang depression,Tarim Basin,China

There exists a petroleum system rich of oil and gas around Halahatang depression, where the oil and gas possess obvious local distinctions of properties in different parts. The research proved that the discovered crude oil and natural gas in the region derived mainly from O₂₊₃ source rock, and the differences of its properties were controlled by the oil and gas filling intensity. The comprehensive study result shows the oil and gas reservoirs of the region mainly underwent three important accumulation phases: late Caledonian-Early Hercynian epoch, late Hercynian epoch, and Yanshan-Himalayan epoch. In the first phase, the oil and gas derived mostly from Cambrian source rock, which formed the primary ancient oil reservoirs, then suffered strong degradation and remained a great quantity of pyrobitumen in the high position of Tabei uplift in the present. In the second phase, the O₂₊₃ source rock of Manjia’er depression started its generation of hydrocarbon, which accumulated in the high position of Tabei up-lift afterwards, and then biodegradated to heavy oil in the late Hercynian epoch. In the last phase, the O₂₊₃ source rock of southern Halahatang depression and margin of Manjia’er depression started its peak of generating liquid hydrocarbon, which mostly accumulated in the trap formed before the Indo-China and Yanshan epoch, and in somewhere the heavy oil suffered dilutions in various degrees or serious gas invading, to lead to obvious crude oil divergence.

     

Geochemical characteristics and accumulation of marine oil and gas around Halahatang depression,Tarim Basin,China

There exists a petroleum system rich of oil and gas around Halahatang depression,where the oil and gas possess obvious local distinctions of properties in different parts.The research proved that the discovered crude oil and natural gas in the region derived mainly from O2 3 source rock,and the differences of its properties were controlled by the oil and gas filling intensity.The comprehensive study result shows the oil and gas reservoirs of the region mainly underwent three important accumulation phases:late Caledonian-Early Hercynian epoch,late Hercynian epoch,and Yanshan-Himalayan epoch. In the first phase,the oil and gas derived mostly from Cambrian source rock,which formed the primary ancient oil reservoirs,then suffered strong degradation and remained a great quantity of pyrobitumen in the high position of Tabei uplift in the present.In the second phase,the O2 3 source rock of Manjia'er depression started its generation of hydrocarbon,which accumulated in the high position of Tabei uplift afterwards,and then biodegradated to heavy oil in the late Hercynian epoch.In the last phase,the O2 3 source rock of southern Halahatang depression and margin of Manjia'er depression started its peak of generating liquid hydrocarbon,which mostly accumulated in the trap formed before the Indo-China and Yanshan epoch,and in somewhere the heavy oil suffered dilutions in various degrees or serious gas invading,to lead to obvious crude oil divergence.     

Geochemical characteristics and accumulation of marine oil and gas around Halahatang depression,Tarim Basin,China

There exists a petroleum system rich of oil and gas around Halahatang depression, where the oil and gas possess obvious local distinctions of properties in different parts. The research proved that the discovered crude oil and natural gas in the region derived mainly from O₂₊₃ source rock, and the differences of its properties were controlled by the oil and gas filling intensity. The comprehensive study result shows the oil and gas reservoirs of the region mainly underwent three important accumulation phases: late Caledonian-Early Hercynian epoch, late Hercynian epoch, and Yanshan-Himalayan epoch. In the first phase, the oil and gas derived mostly from Cambrian source rock, which formed the primary ancient oil reservoirs, then suffered strong degradation and remained a great quantity of pyrobitumen in the high position of Tabei uplift in the present. In the second phase, the O₂₊₃ source rock of Manjia’er depression started its generation of hydrocarbon, which accumulated in the high position of Tabei up-lift afterwards, and then biodegradated to heavy oil in the late Hercynian epoch. In the last phase, the O₂₊₃ source rock of southern Halahatang depression and margin of Manjia’er depression started its peak of generating liquid hydrocarbon, which mostly accumulated in the trap formed before the Indo-China and Yanshan epoch, and in somewhere the heavy oil suffered dilutions in various degrees or serious gas invading, to lead to obvious crude oil divergence.     

Detection and significance of higher thiadiamondoids and diamondoidthiols in oil from the Zhongshen 1C well of the Tarim Basin,NW China

Oil and gas breakthroughs have been achieved in the Zhongshen 1(ZS1) and 1 C(ZS1 C) wells in Cambrian pre-salt from the Tarim Basin in northwest China. However, Middle and Lower Cambrian reservoirs reveal substantial differences in the geochemistry and secondary alteration characteristics between the oils collected from the two wells. High concentrations of thiadiamondoids and diamondoidthiols, including thiatetramantanes, tetramantanethiols, thiapentamantanes, and pentamantanethiols, are detected in the organic sulfur compound fraction of concentrated oil collected from the ZS1 C well, which samples the Lower Cambrian Xiaoerbulake Formation. Higher diamondoids, such as tetramantanes, pentamantanes, hexamantanes, and cyclohexamantane, also occur in the saturate fractions of the concentrated ZS1 C oil. The presence of these compounds is verified by mass spectra analysis and comparison with previous studies. During thermochemical sulfate reduction(TSR), the cage of higher diamondoids is interpreted to open because of sulfur radicals forming open-cage higher diamondoid-like thiols, followed by cyclization that leads to the formation of high thiadiamondoids. Using D_(16)-adamantane as an internal standard, the concentrations of lower diamondoids and thiadiamondoids of non-concentrated Cambrian oil from well ZS1 C are 83874 and8578 μg/g, respectively, which are far higher than Cambrian oil from well ZS1 and most Ordovician oils in the Tarim Basin. The high concentrations of lower thiadiamondoids and occurrence of higher thiadiamondoids and diamondoidthiols support that the oil from well ZS1 C is a product of severe TSR alteration.     

Hydrogen isotope composition of natural gases from the Tarim Basin and its indication of depositional environments of the source rocks

By measuring carbon and hydrogen isotope compositions for C1, C2 and C3 of 74 gas samples, natural gases from the Tarim Basin can be divided into six groups on the basis of their origins: (1) coal-type gas derived from coal measures; (2) coal-type gas generated from the T-J lacustrine mudstones; (3) oil-type gas derived from the Cambrian and low Ordovician marine source rocks; (4) oil-type gas from the source rocks deposited in the marine-transitional facies; (5) mixing gas between gas derived from the Carboniferous transitional source rocks and the Mesozoic humic gas, and (6) mixing gases of thermal genetic gas and little deep gas in the Southwest depression of the Tarim Basin. The δ D values of methane in natural gases originating from different type kerogens are affected by both palaeo-environments of the source rock formation (kerogen types) and thermal maturity, with sedimentary environment (kerogen type) as the main controlling factor. Under the similar thermal maturity, the hydrogen isotope composition of methane is more enriched in deuterium in marine environments than lacustrine one. With the increase of thermal maturity and the increase of carbon atomic numbers of gaseous alkanes, the hydrogen isotopes become enriched in deuterium. The δ D values of ethane and propane (δ D2, δ D3) are controlled mainly by thermal maturity and to a lesser degree by sedimentary environment of the source rock formation. The partial reversal of hydrogen isotopes for gaseous alkanes would be related to the microbial oxidation, mixing of sapropelic and humic gases and / or mixing of gases from similar kerogen sources with various thermal maturities. In the oil-type gas, the sulfate reduction reaction would result in the reversed order of δ D1 and δ D2 (e.g. δ D1>δ D2).     

太湖表层沉积物多环芳烃的空间分布、来源及其风险

随着太湖流域社会与经济的发展,多环芳烃(PAHs)在各种环境介质中逐渐累积,污染日益严重,可能对太湖生态环境及周边人体健康构成威胁。为探究太湖沉积物PAHs的来源及生态风险,于2021年12月在太湖采集30个表层沉积物样品,利用气相色谱-质谱联用仪(GC-MS)检测样品中16种PAHs含量;利用受体模型和苯并[a]芘(BaP)毒性当量法进行来源解析及生态风险评估,并将各来源贡献与毒性当量浓度相结合,量化源风险。结果表明,太湖表层沉积物中16种PAHs总含量介于124~592 ng/g之间,平均值为294 ng/g,中值为279 ng/g;高环多环芳烃(HMW PAHs)为主要组分,占∑PAHs的67%。高含量区域位于竺山湾、梅梁湾、贡湖湾和西太湖,与国内外其他湖泊沉积物相比,太湖沉积物PAHs含量处于较低水平。源解析的结果表明,太湖表层沉积物中PAHs交通排放源贡献率为29.1%、煤炭燃烧源贡献率为26.7%、生物质燃烧源贡献率为28.7%、石油源贡献率为15.6%。生态风险评价结果表明,交通排放源、生物质燃烧源、煤炭燃烧源和石油源的BaP毒性当量含量(TEQ_BaP)均值分别为19.34、17.81、16.33和9.1 ng/g,均小于70 ng/g,几乎处于无风险水平。西太湖、贡湖湾和梅梁湾的部分区域ΣTEQ_BaP大于70 ng/g属于潜在风险区,具有一定潜在毒性。在后续的污染治理中应重点关注太湖西北部地区污染物的排放。本研究可为沉积物中PAHs污染的研究提供数据支撑,为地方政府精准、高效地管控PAHs污染提供理论依据。     

Magnetic and mineralogical characteristics of hydrocarbon microseepage above oil/gas reservoirs of Tuoku region, northern Tarim Basin, China

The Tuoku region in northern Tarim Basin of China is a key area for studying oil/gas reservoir rocks. The magnetic and mineralogical parameters of well cuttings from two wells, well S₇, situated on oil/gas field, and well S₆, at an oil/water interface, were measured. The two wells are located in the same structure with similar strata and types of lithology, but well S₆ is a showing well of oil and gas 5 km northwest of well S₇. The purpose of this paper is to evaluate the possibility and distribution of secondary magnetic alteration that may have occurred due to hydrocarbon migration above an oil/gas accumulation. It is concluded that the magnetism of well cuttings from major strata in well S₇, including source rocks, oil reservoir rocks and cap rocks, and in Quaternary (Q) soil is higher than that from well S₆. The Cambrian oil-bearing strata and cap rocks have even higher magnetism in well S₇. The shape and parameters of magnetic hysteresis loops indicate that soft (H _c<20 mT,H _s<0.3 T) ferrimagnetic components dominate the magnetic carriers within the strongly magnetic strata of well S₇, whereas a mixed paramagnetic and ferrimagnetic distribution occurs in well S₆ (for example, low coecivityH _c and nonsaturating magnetized character). Analysis of heavy minerals shows that the contents of iron oxide (magnetite, maghemite and hematite) in well S₇ are often higher than those in well S₆. The magnetite content in samples of cuttings from Cambrian rocks can reach 9.7% in oil-bearing strata in well S₇, and in strata Ekm and N₁j are 1.215% and1.498%, respectively. Typical spherical magnetite grains are found within the main source rocks and the soils in well S₇. By analysis of surface microtexture and of trace element contents, we infer that the spherical magnetite is composed of aggregates of ultrafine particles that are probably authigenic magnetite formed in a hydrocarbon halo background. Project supported by the National Natural Science Foundation of China and the Geological Industry Foundation of China (Grant No. 49374216) and Foundation of the State Key Laboratory of Oil/Gas Reservoir Geology and Exploitation of China (Grant No. 9608).     

Characteristics of chlorine isotope distribution and analysis on sylvinite deposit formation based on ancient salt rock in the western Tarim Basin

The Tarim Basin, located in Xinjiang (Fig. 1), is the largest deposit basin with an area of about 560000 km2 in China. From late Triassic period to early Miocene, two huge subbasins developed, named the Kuqa sub-basin at the foot of the Tianshan Mountains in the north and the Shaqa subbasin at the foot of the Kunlun Mountains in the south of the Tarim Basin. During the late Cretaceous to early Tertiary period, the Paleo-me- diterranean seawater repetitively invaded into the Shaqa subbas…     

Crude-oil hydrocarbon composition characteristics and oil viscosity prediction in the northern Songliao Basin

Crude oil hydrocarbon composition characteristics and oil viscosity prediction are important bases in petroleum exploration.A total of 54 oil/heavy-oil samples and 17 oil sands were analyzed and quantified using both comprehensive 2D gas chromatography(GC×GC)and comprehensive 2D gas chromatography/time-of-flight mass spectrometry(GC×GC/TOFMS).The results show that crude oil in the West slope is mainly heavy oil and its hydrocarbon composition is characterized overall by paraffinsmono-aromaticsnaphthenesnon-hydrocarbonsdi-aromaticstri-aromaticstetra-aromatics.Aromatics are most abundant and non-hydrocarbons are least abundant,whilst content differences among paraffins,naphthenes,aromatics,and non-hydrocarbons are less than 15%.There are two types of heavy oil,secondary type and mixing type.Biodegradation is the main formation mechanism of heavy oil.Biodegradation levels cover light biodegradation,moderate biodegradation,and severe biodegradation.With increasing biodegradation,paraffin content decreases while contents of aromatics and nonhydrocarbons increase.In contrast,naphthene content increases first and then decreases with increasing biodegradation.In severe biodegradation stage,naphthenes decrease more quickly than aromatics and non-hydrocarbons.This provides a new method for studying oil/heavy-oil biodegradation mechanism and biodegradation resistance of different hydrocarbons at different biodegradation stages.In the Longhupao-Daan terrace and Qijia-Gulong depression,most crude oil is conventional oil.Its composition is dominated by paraffins with the lowest content of aromatics.In some casual oil wells from the Longhupao-Daan terrace,crude oil from Saertu oil reservoirs is moderately biodegraded whereas crude oil from Putaohua oil reservoir is lightly biodegraded.Chemical parameters using saturate hydrocarbons and aromatics are usually not suitable for determining organic type and thermal maturity of biodegraded oil,especially of moderately or severely biodegraded oil,whilst Ts/(Ts+Tm)ratio can be used to determine thermal maturity of both conventional crude oil and heavy oil.     

Geochemical significance of tricyclic and tetracyclic terpanes in source rock extracts from the Offshore Niger Delta Basin,Nigeria

Tricyclic and tetracyclic terpanes are important constituents of crude oil and source rock extracts.However,they have not been reported in the Offshore Niger Delta Basin,Nigeria.Thus,the present study investigated the geochemical significance of tricyclic and tetracyclic terpanes in source rock extracts from the Offshore Niger Delta Bain,Nigeria with gas chromatography-mass spectrometry(GC-MS).The total relative abundances of tricyclic terpanes,C_(19)TT-C_(21)TT,and C23 TT in the rock samples ranged from 82.50 to 96.37%,50.08 to 74.17%,and 25.83 to 49.92%,respectively.These values showed the source rocks were formed from a mixed origin(terrestrial and marine).Among the tricyclic and tetracyclic terpanes identified in the rock extracts,the conventional(C_(20)TT,C_(23)TT,C_(24)TT,C_(24)TeT) and recent(Y1,X1,Z1)were more prominent than all others,indicating mixed input of terrigenous and marine organic matter.The C_(24)TT/C_(23)TT,C_(24)TeT/(C_(24)TeT+C_(26)TT),C_(19)TT/C_(23)TT,C_(20)TT/C_(23)TT,C_(25)TT/C_(24)TeT,C_(25)TT/C_(26)TT,C_(19)TT/C_(20)TT,C_(24)TeT/C_(26)TT,Z1/(Z1+C_(24)TT),and Y1/(Y1+C~(24)TT)in the rock samples range from 0.33 to 1.30,0.76 to 0.90,0.18 to 0.73,0.34 to 1.05,0.33 to 1.74,0.30 to 1.39,0.31 to0.89,1.66 to 4.33,0.36 to 0.83,and 0.34 to 0.79,respectively.These values further showed that the rock samples were formed from mixed input of terrigenous and marine organic matter and deposited under oxic to suboxic conditions in lacustrine-fluvial/deltaic environments.Also,the C_(24)TeT/C_(20-26)TT,C_(24)TeT/C_(30)HOP,and C_(23)TT/C_(30)HOP ranged from 0.16 to 0.45,0.02 to 0.42,and 0.01 to 0.48,respectively.This range of values suggests that source rocks were within immature to early mature stage.Thus,this study showed that tricyclic and tetracyclic terpanes were effective in determining the origin,depositional environments,and thermal maturity of source rocks in the Niger Delta Basin,Nigeria.     

Carbon isotopic composition and genetic types of natural gas in the Sichuan Basin,China

The origin and genetic types of natural gas in the Sichuan Basin are still disputed.To classify the origin and genetic types in different areas,the paper analyzes the carbon isotopic composition of gases and geologic features in the Sichuan Basin.The results showed that the gas sourced from terrestrial layers is typically characterized by terrestrial origin and was mainly accumulated nearby to form reservoir.The carbon isotopic composition of gas showed a normal combination sequence distribution,suggesting that natural gas in continental strata is not affected by secondary alteration or that this deformation is very weak.The gas source is singular,and only gas from the southern and northern Sichuan Basin shows the characteristic of mixed sources.However,marine gas presents the characteristics of an oil-formed gas.The carbon isotopic composition of natural gas in the western and central part of the basin mostly distributes in a normal combination sequence,and few of them showed an inversion,indicating that the gas perhaps had not experienced secondary alteration.The carbon isotopic composition of marine-origin gas in the southern,northern and eastern Sichuan Basin displays a completely different distribution pattern,which is probably caused by different mixing ratio of gas with multi-source and multi-period.     

Hydrogen isotopic compositions, distributions and source signals of individual n-alkanes for some typical crude oils in Lunnan Oilfield, Tarim Basin, NW China

Petroleum mainly comprises carbon and hydrogen elements. The stable carbon isotopic analysis for whole oil was undertaken as early as the 1930s. After decades, the stable carbon isotopic analytical methods have been developed from analysis for whole oil and oil fractions (e.g., saturated, aromatic and polar frac-tions) into compound-specific isotopic analysis with the emergence of the newly developed GC-C-IRMS analytical technique. Especially, by using com-pound-specific isotopic analytical…     

Mercury concentration in natural gas and its distribution in the Tarim Basin

Here I collected natural gas samples from 41 industrial gas wells in the Tarim Basin,and studied the mercury distribution in the area.My data show that there is certain regularity in the distribution of mercury in the Tarim Basin.Generally,the mercury concentration is high at the edge of the basin and low in the central basin.The highest mercury concentration occurs in the Southwest Depression,ranging from 15428.5 to 296763.0ng/m3 with an average of 156095.7ng/m3,followed by the Kuqa Depression ranging from 15.0 to 56964.3ng/m3 with an average of 11793.7ng/m3,and the Hade oil and gas field in the North Depression has the lowest mercury concentration ranging from 17.7 to 3339.5ng/m3 with an average of 1678.6ng/m3.The mercury concentrations in the natural gases of different structural units are various,with the highest mercury concentration in the zone of strong structural activity of Southwest Depression.It is profitable of Hg accumulation in the self sourced and self accumulated gas reservoirs or volcanic existence;in contrast,the low Hg concentration exists in the secondary gas reservoir.The mercury concentration in the natural gas generated under continental depositional environment is higher than that in marine gas.Therefore,the mercury concentration in the natural gases is constrained by gas genesis,depositional environment of source rocks,tectonic activity,and volcanic activity,and the tectonic activity is the main factor for the mercury concentration in the natural gas,followed by volcanic activity and depositional environments.     

Strontium and its isotopic composition in interstitial waters of marine carbonate sediments

The concentrations and isotopic compositions of strontium in interstitial waters from several DSDP sites, where sediments consist chiefly of carbonate oozes and chalks, are used as indicators of carbonate diagenesis by reference to a recently-produced curve showing detailed variations in the⁸⁷Sr/⁸⁶Sr ratio of seawater with time. Carbonate sediments of the Walvis Ridge show increases in interstitial Sr²⁺ concentrations in the upper carbonate-ooze sections with the highest concentrations near the ooze-chalk boundary where maximum rates of carbonate recrystallization occur. Below this, in situ production of Sr²⁺ diminishes and there is a diffusive flux of Sr to an underlying sink, presumably volcanogenic sediments or basalts, leading to Sr isotopic disequilibrium between carbonates and interstitial waters. In some other sites, however, there is no apparent Sr sink at depth and isotopic equilibrium is retained. Overall, diffusive smoothing of profiles exerts an important control on the⁸⁷Sr/⁸⁶Sr ratios, although lower ratios than contemporaneous seawater values in the carbonate oozes often correlate with zones of Mg²⁺ loss and reflect a combination of a flux of Sr²⁺ from the zone of maximum recrystallization rates together with a contribution from the in situ alteration of volcanic matter.     

Geological characteristics and shale gas distribution of carboniferous mudstones in the Tarim Basin,China

Extant research on Paleozoic mudstone is well developed in the Tarim Basin, while the research on Carboniferous mudstone is relatively weak. Through systematic study of lithology, geochemical characteristics,reservoir characteristics and gas–bearing properties of Carboniferous mudstone in the Tarim Basin, this study aims to provide a geological basis for the Paleozoic shale gas exploration and development, favorable zone optimization, and resource potential evaluation in the Tarim Basin. The results show that the sedimentary environments of organic-rich mudstone in the study area were mainly basin facies and slope facies. Lithology is dominated by black carbonaceous mudstone, followed by calcareous mudstone, siliceous mudstone, and siliceous rocks. Mudstone is mainly developed in the Kalashayi Formation,which is located in the Bachu and Markit slope belt, with the cumulative thickness of 30–200 m. The organic carbon content is commonly more than 0.4%, and the organic matter types are type II and type III. Thermal evolution degree is widely distributed from a low mature to over mature stage, and different tectonic units have a greater difference. The contents of quartz plus feldspar are between 12% and 82.5%, with an average of 45.8%. Thecontent distribution of clay mineral is from 12% to 57%,with an average of 38.2%. Carbonate minerals(mainly siderite) content is below 50%. The brittle mineral content of the mudstone is approximately 65%, with a strong compressibility, and the mudstone has the material basis of forming crack and natural fracture. Microscopic pores in micro–nanometer level are well developed in the mudstone, including micro bedding joint, microcrack,interbedded pores of clay mineral, nanoscale intragranular or edge pores in the massive organic matter, bioclastic micropores, and mineral dissolution pores, etc. According to the standards provided by the Ministry of Land and Resources in China, the Kalashayi Formation in Bamai Area is a favorable area for shale gas development.     

Evolution and global correlation for strontium isotopic composition of marine Triassic from Huaying Mountains,eastern Sichuan,China

Strontium isotope stratigraphy (SIS) has progressively become an efficient chemostratigraphic tool in the research and correlation of global geological events, such as global sea level fluctuations, orogeny, and paleoclimatic and paleoenvironmental changes. In this paper, 87Sr/86Sr ratios of the Triassic marine carbonate rock samples from Huaying Mountains, eastern Sichuan are measured, and the corre-sponding Sr-isotopic curve is constructed, based on the fundamental principle of strontium isotope stratigraphy, analysis of rock fabric, luminescent intensity, chemical composition and representative evaluation for the coeval seawater information. The 87Sr/86Sr ratios show a rapid rise from 0.70721 near the Permian-Triassic transition to 0.70830 at the end of Early Triassic, and then they decline rapidly to 0.70787 in the early Middle Triassic. These data are generally coincident with 87Sr/86Sr ratios of coeval seawater from previous papers, and the curve is also similar to other previous curves. This indicates that the global geological events are the most important controlling factors to the strontium isotope evolution of the global seawater in the Early and Middle Triassic.     

The noble gas isotope geochemical composition of chert at the bottom of Cambrian in Tarim Basin,China

In the Tarim Basin, black shale series at the bottom of Cambrian is one of the important marine facies hydrocarbon source rocks. This research focuses on the analysis of the isotope of noble gas of 11 cherts. The R/R _a ratio of chert in the Keping area is 0.032–0.319, and ⁴⁰Ar/³⁶Ar is 338–430. In Quruqtagh the R/R _a ratio is 0.44–10.21, and ⁴⁰Ar/³⁶Ar is 360–765. The R/R _a ratio of chert increases with ⁴⁰Ar/³⁶Ar from the west to the east accordingly. They have evolved from the crust source area to the mantle source area in a direct proportion. Surplus argon ⁴⁰Ar_E in chert is in direct proportion to the R/R _a ratio, indicating that it has the same origin of excess argon as in fluid and mantle source helium. Comparison of the R/R _a ratios between the west and the east shows that the chert in the eastern part formed from the activity system of the bottom hydrothermal venting driven by the mantle source, where the material and energy of crust and mantle had a strong interaction in exchange; whereas in the western part, chert deposited from the floating of hydrothermal plume undersea bottom, which is far away from the centre of activities of the hydrothermal fluid of ocean bottom. In addition, from noble gas isotope composition of chert, it is suggested that the ocean anoxia incident happened at the black shale of the Cambrian bottom probably because of the large-scaled ocean volcanoes and the following hydrothermal activities.

     

The noble gas isotope geochemical composition of chert at the bottom of Cambrian in Tarim Basin,China

In the Tarim Basin, black shale series at the bottom of Cambrian is one of the important marine facies hydrocarbon source rocks. This research focuses on the analysis of the isotope of noble gas of 11 cherts. The R/R _a ratio of chert in the Keping area is 0.032–0.319, and ⁴⁰Ar/³⁶Ar is 338–430. In Quruqtagh the R/R _a ratio is 0.44–10.21, and ⁴⁰Ar/³⁶Ar is 360–765. The R/R _a ratio of chert increases with ⁴⁰Ar/³⁶Ar from the west to the east accordingly. They have evolved from the crust source area to the mantle source area in a direct proportion. Surplus argon ⁴⁰Ar_E in chert is in direct proportion to the R/R _a ratio, indicating that it has the same origin of excess argon as in fluid and mantle source helium. Comparison of the R/R _a ratios between the west and the east shows that the chert in the eastern part formed from the activity system of the bottom hydrothermal venting driven by the mantle source, where the material and energy of crust and mantle had a strong interaction in exchange; whereas in the western part, chert deposited from the floating of hydrothermal plume undersea bottom, which is far away from the centre of activities of the hydrothermal fluid of ocean bottom. In addition, from noble gas isotope composition of chert, it is suggested that the ocean anoxia incident happened at the black shale of the Cambrian bottom probably because of the large-scaled ocean volcanoes and the following hydrothermal activities.