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1.
Relatively little work has been published on the correlation between the light hydrocarbon distributions in reservoir fluids and their proposed source rocks [Philippi, G. T. (1981)]. The aim of our work was to study this relationship in detail for samples from Mid-Norway. The main source rocks offshore Mid-Norway are the marine shales of the Late Jurassic Spekk Formation and the coals and paralic shales of the Early Jurassic Åre Formation. Reliable light hydrocarbon (C4–C13) data for source rock samples were acquired by thermal extraction-GC of the source rocks. Of these, notably the hydrocarbons in the C6–C8 range (routinely measured in test fluids) were used to discriminate between the Spekk and Åre Formation samples. A total of twenty-six samples from the Spekk Formation and twenty-four samples from the Åre Formation at different maturity levels and facies were analyzed. In general, the two source rock types differ in their light hydrocarbon composition by the presence of relatively more aromatics and cyclohexanes in the Åre samples, while the Spekk samples are richer in cyclopentanes and acyclic hydrocarbons. We show that source rock facies is a more important indicator of light hydrocarbon composition than maturity variation. Differences in the chemical composition, which can be used to discriminate between the two source rocks, were supported by differences in the carbon isotope composition of individual components of the same fraction, as determined by GHM-IR-MS analysis of eleven samples. Further, the light hydrocarbon compositions of reservoir fluids (oils and condensates) were compared with those for the source rock(s). Sixty-six gas chromatograms of oils and condensates, representing most of the known petroleum accumulations in Mid-Norway, were collected. Of these, five oil samples were selected for detailed isotopic analysis of individual components (GC-IR-MS). When using a classification scheme based on data from sediment samples, data for the light hydrocarbon fraction of oils and condensates indicate that the Spekk Formation is the dominant source for most of the fields from Mid-Norway, with a significant contribution from the Åre Formation being detected principally in one field. Differences in the chemical composition of the C6–C8 fractions were supported by differences in the carbon isotope composition of individual components, which also discriminate between the oils. Although the classification diagrams used in this study are based on source rock data from Mid-Norway, the method can be applied to other areas, providing that the diagrams are calibrated with source rock data from the area of interest. 相似文献
2.
The equilibrium thermodynamic calculations made for C-H and C-H-N-O-S systems show that the mantle might contain a fluid consisting
of heavy (high-molecular) hydrocarbons (HHC) and their derivatives, as well as of inorganic gases (H2O, CO2, N2, NH4, H2S, etc.). In the range of diamond-graphite phase transition, the HHC are decomposed to form methane, its nearest homologues,
and graphite. The geochemical and experimental data by different authors point to possible HHC occurrence in the upper mantle.
These results confirm the concept by Dmitrievskii (2006) that the deep fluids might be lifted to the crustal waveguide to
fill its fractures and cavities. Owing to compaction, the fluids are squeezed from the waveguide and lifted into sedimentary
layers to form the commercial hydrocarbon deposits. Resulting from the “washing“ of sedimentary rocks with the fluids, hydrocarbon
gases and oil of organic origin might be formed. 相似文献
3.
The presence of shale oil in the Cretaceous Hengtongshan Formation in the Tonghua Basin, drilled by the well TD-01, has been discussed in this geological investigation for the first time. To evaluate the high-quality source rocks of Cretaceous continental shale oil, the distribution characteristics and the evolution of the ancient environment, samples of shale were systematically analyzed in terms of sedimentary facies, organic geochemistry, and organic carbon isotopic composition. The results demonstrate that a TOC value of 1.5% represents the lower-limit TOC value of the high-quality source rocks. Source rocks have an aggregate thickness of 211 m and contain abundant organic matter, with TOC values of 2.69% on average and a maximum value over 5.44%. The original hydrocarbon-generative potential value(S_1+S_2) is between 0.18 mg/g and 6.13 mg/g, and the Ro is between 0.97% and 1.40%. The thermal maturation of the source rocks is relatively mature to highly mature. The δ13C value range is between -34.75‰ and -26.53‰. The ratio of saturated hydrocarbons to aromatic hydrocarbons is 1.55 to 5.24, with an average of 2.85, which is greater than 1.6. The organic types are mainly type Ⅱ_1, followed by type Ⅰ. The organic carbon source was C_3 plants and hydrophytes. The paleoclimate of the Hengtongshan Formation can be characterized as hot and dry to humid, and these conditions were conducive to the development of high-quality source rocks. A favorable paleoenvironment and abundant organic carbon sources provide a solid hydrocarbon generation base for the formation and accumulation of oil and gas in the shale of the Tonghua Basin. 相似文献
4.
Coal beds of the Upper Cretaceous Fruitland Formation in the San Juan Basin of northwestern New Mexico and southwestern Colorado have significant liquid hydrocarbon generation potential as indicated by typical Rock-Eval Hydrogen Indexes in the range of 200–400 mg hydrocarbon/g organic carbon (type II and III organic matter). Small, non-commercial quantities of oil have been produced from the coal beds at several locations. The oils are characterized by high pristane/phytane (ca 4) and pristane/n-C17 ratios (ca 1.2), abundant C21+ alkanes in the C10+ fraction with a slight predominance of odd carbon-numbered n-alkanes, abundant branched-chain alkanes in the C15+ region, and a predominance of methylcyclohexane in the C4----C10 fraction. The oils are indigenous to the Fruitland Formation coals and probably migrated at thermal maturities corresponding to vitrinite reflectance values in the range 0.7–0.8%. Although the oils found to date are not present in commercial amounts, these findings illustrate the potential of some coals to generate and expel oil under conditions of moderate thermal heating. 相似文献
5.
The role of metamorphic processes (including postmagmatic ones) in the origin of mineral assemblages is estimated for the
layered unit (LU) and barren rocks (BR) in the Pana Intrusion. Numerical simulations indicate that metamorphic processes simultaneously
modified the mineralogical composition of the rocks, Pt and Pd compounds, and the fluids. The process resulted in systematic
changes in the mineralogical and fluid composition and is realistically reproduced by physicochemical numerical simulations.
Our results make it possible to estimate the effect of P-T parameters on the composition of metallic Pt and Pd and their sulfides, selenides, and tellurides and the composition of
the fluid phase during the transformations and localization of the PGE ore mineralization. 相似文献
6.
LIU Shugen HUANG Wenming JANSA Luba F. WANG Guozhi SONG Guangyong ZHANG Changjun SUN Wei MA Wenxin 《《地质学报》英文版》2014,88(5):1466-1487
Hydrothermal Dolomite （HTD） is present in the Upper Sinian （Upper Proterozoic） Dengying Formation, east Sichuan Basin, China. The strata are comprised by primary dolomite. The HTD has various textures, including zebra dolomite, subhorizontal sheet-like cavities filled by saddle dolomite and breccias cemented by saddle dolomites as well occur as a fill of veins and fractures. Also co-occur MVT type lead-zinc ores in the study area. The δ13C and δ18O isotopes of HTD in the Upper Sinian Dengying Formation are lighter than those of the host rocks, while STSr/86Sr is higher. The apparent difference in carbon, oxygen and strontium isotopes, especially the large difference in S7Sr/S6Sr isotopes ratio indicate crystallization from hot basinal and/or hydrothermal fluids. Saddle dolomite was precipitated at temperatures of 270-320℃. The diagenetic parasequences of mineral assemblage deposited in the Dengying Formation are： （1） dolomite host rock →sphalerite-galena-barite-fluorite; （2） dolomite host rock →saddle dolomite →quartz; （3） dolomite host rock →saddle dolomite→bitumen; （4） dolomite host rock →saddle dolomite →barite. The mean chemical composition of the host dolomite matrix and HTD didn＇t change much during hydrothermal process. The fluids forming the HTDs in the Dengying Formation were mixtures of freshwater from the unconformity at the top of Sinian, fluids from diagenetic compaction and hydrocarbon generation ＆ expulsion from the Lower Cambrian Niutitang Formation mudstones or the Doushantuo Formation silty mudstones, and hydrothermal fluids from the basement. The hydrocarbon reservoirs associated with the HTD were mostly controlled by the basement faults and fractures and karsting processes at the unconformity separating Sinian and Cambrian strata. The hydrocarbon storage spaces of HTD included dissolved cavities and intercrystalline pores. Dissolution cavities are extensive at the top of Dengying Formation, up to about 46m below the unconformity between Sinian an 相似文献
7.
Three successive metamorphic stages M1, M2 and M3 have been distinguished in polymetamorphic granulite facies quartz-feldspathic gneisses from the Seiland Igneous Province, Caledonides of northern Norway. An early period of contact metamorphism (M1; 750–950°C, ca. 5 kbar) was followed by cooling, accompanied by strong shearing and recrystallization at intermediate-P granulite facies conditions (M2; 700–750°C, 5–6kbar). High-P granulite facies (M3; ca. 700°C, 7–8 kbar) is related to recrystallization in narrow ductile shear zones and secondary growth on M2 minerals. On the basis of composition, fluid inclusions in cordierite, quartz and garnet can be divided into three major types: (1) CO2 inclusions; (2) mixed CO2–N2 inclusions; (3) N2 inclusions. Fluid chronology and mineral assemblages suggest that the earliest inclusions consist of pure CO2 and were trapped at the M1 contact metamorphic episode. A carbonic fluid was also present during the intermediate-P granulite facies M2 metamorphism. The CO2-rich inclusions in M2 garnet can be divided into two generations, an early lower-density and a late higher-density, with isochores crosscutting the P-T box of M2 and M3, respectively. The nitrogen-rich fluids were introduced at a late stage in the fluid evolution during the high-P M3 event. The mixed CO2–N2 inclusions, with density characteristics compatible with M3 conditions, are probably produced from intersection between pre-existing pure CO2 inclusions and N2 fluids introduced during M3. The fluid inclusion data agree with the P-T evolution established from mineral assemblages and mineral chemistry. 相似文献
8.
William M. Lamb Philip E. Brown John W. Valley 《Contributions to Mineralogy and Petrology》1991,107(4):472-483
Investigation of fluid inclusions in granitic and cale-silicate gneisses from the Adirondack Mountains, New York, has revealed the presence of various types, including: (1) CO2-rich, (2) mixed H2O–CO2±salt and (3) aqueous inclusions with no visible CO2. Many, if not all, of these inclusions were trapped or modified after the peak of granulite facies metamorphism, as shown by textural relations or by the lack of agreement between the composition of the fluids found in some inclusions and the composition of the peak-metamorphic fluid as estimated from mineral equilibria. Many fluid inclusions record conditions attained during retrograde cooling and uplift, with minimum pressures and temperatures of 2 to 3 kbar and 200 to 300°C. The temperatures and pressures derived from the investigation of these inclusions constrain the retrograde P-T path, and the results indicate that a period of cooling with little or no decompression. 相似文献
9.
James A. D. Connolly Volkmar Trommsdorff 《Contributions to Mineralogy and Petrology》1991,108(1-2):93-105
Isothermal or isobaric phase diagram sections as a function of fluid composition (X
F) are widely used for interpreting the genetic history of metacarbonate rocks. This approach has the disadvantages that: (1)
the influence of a key metamorphic variable, either pressure (P) or temperature (T), is obscured; (2) the diagrams are inappropriate for systems that are not fluid-saturated. These problems are avoided by
constructing phase-diagram projections in which the volatile composition of the system is projected onto a P-T coordinate frame, i.e., a petrogenetic grid. The univariant curves of such P-T projections trace the conditions of the invariant points of isothermal or isobaric phase-diagram sections, thereby defining
the absolute stability of high-variance mineral assemblages, with and without a coexistent fluid phase. Petrogenetic grids
for metacarbonate rocks are most useful for the study of regional metamorphism and for systems in which fluid composition
has not been externally controlled. A calculated example of a P-T projection for the system CaO−MgO−SiO2−H2O−CO2 suggests that many assemblages (e.g., calcite +tale, enstatite+fluid, magnesite+tremolite, antigorite+diopside+dolomite,
and calcite+forsterite+tremolite) in mixed-volatile systems have stability fields that make them useful as P-T indicators. Consideration of the principles governing projection topology demonstrates that the univariant curves around
a fluid present invariant point cannot be oriented independently with respect to the direction of compositional variation
in the fluid phase. This has the interesting predictive implication that if the direction of compositional variation along
one univariant curve around an invariant point is known, then the direction of compositional variation along the remaining
curves can be determined solely from topologic constraints. The same constraints can be applied to systems containing simple
mineral solutions or melts in order to predict compositional variations. 相似文献
10.
Application of quantitative grain fluorescence techniques to study subtle oil migration pathway of lithological reservoir 总被引：1，自引：0，他引：1
This paper analyzes the quantitative grain fluorescence (QGF) and quantitative grain fluorescence on extract (QGF-E) properties
of 101 rock samples by using quantitative grain fluorescence techniques. The samples are collected from five wells in tight
sandstone and thin siltstone in the third sector of the Shahejie Formation in the Niuzhuang sag of the Dongying depression.
It was observed that both the tight sandstone and thin siltstone show relatively high fluorescence intensity of hydrocarbon,
which suggests that they are possibly good subtle oil-migration pathways in the present or geological time. These thin subtle
oil-migration pathways afford important clues for the researches on hydrocarbon accumulation in lithological reservoirs in
the middle and lower of Es
3 in deep sag zone, which has the hydrocarbon source from the upper of Es
4 when there is no apparent fault playing oil migration conduits to connect lithologic traps and deep source rocks. This study
shows good prospect of QGF techniques in discriminating oil migration pathways and paleo-oil zones. The results of this study
may be of great significance to the researches on hydrocarbon accumulation mechanism of subtle reservoirs in the Dongying
depression and other areas.
__________
Translated from Acta Geologica Sinica, 2007, 81(2): 250–254 [译自: 地质学报] 相似文献
11.
《Cretaceous Research》2008,29(1):1-8
Macromolecular analysis of fossil fish scales from the Cretaceous Las Hoyas Formation (using pyrolysis-gas chromatography-mass spectrometry) revealed a dominant aliphatic composition (C8 to C22) whereas modern fish scale is proteinaceous (largely collagenous). Structural analysis of the aliphatic polymer using thermochemolysis revealed the importance of ester linkages; saturated fatty acids C14 to C18 (particularly C16) are the most abundant. These acid components and their unsaturated counterparts are evident in the lipid composition of modern fish scales. Thus, the aliphatic composition of the fossil scales is probably a result of the incorporation of lipids (including a C19 aromatic hydrocarbon) from the original indicating preservation by in situ polymerization of labile aliphatic components. Fossil arthropods and plants from the same deposit also show a dominant aliphatic macromolecular component, likely derived predominantly by crosslinking of free lipid precursors. Differences in the relative distribution of molecular components indicate likely chemosystematic differences between different fossil groups. 相似文献
12.
The high-pressure granulites of the Uluguru Mountains are part of the Pan-African belt of Tanzania, the metamorphic evolution
of which is characterized by an anticlockwise P-T path. Mineral assemblages that represent distinct metamorphic stages are selected for fluid inclusion studies in order to
deduce the fluid evolution in metapelites and pyroxene granulites from the prograde to the retrograde stage. Fluid inclusion
data improve the petrologically derived P-T path and confirm the anticlockwise evolution. Fluid inclusions in quartz enclosed in garnet porphyroblasts in metapelites
preserve prograde fluids of CO2–N2 composition and later-trapped pure CO2. During isochoric heating at temperatures near the peak of metamorphism, deformation and recrystallization led to fluid homogenization
yielding N2-poor CO2 composition in the metapelites. Near-peak CO2–N2 fluid inclusions in quartz of metapelites and CO2 inclusions in garnet-pyroxene granulites are characterized by perfect negative crystal shape. Garnet formed in veins and
as coronas around orthopyroxene represent the near-isochoric/isobaric cooling stage which is characterized by high-density
CO2-rich fluid inclusions. Up to 15 mol% N2 in some primary CO2 inclusions in corona garnet indicate small-scale fluid heterogeneity during the static garnet growth. The fact that high-density
fluid inclusions are preserved, suggests a shallow dP/dT slope of the uplift path. Nevertheless, some fluid inclusions decrepitated or re-equilibrated and low-density CO2 inclusions were trapped in the garnet-pyroxene granulite while N2–CH4 inclusions formed in the metapelites. Different fluid compositions in metapelite and metabasite argue for an internal control
of the fluid composition by phase equilibria. In shear zones where the pyroxene granulite was transformed into scapolite-biotite
schist, CO2–N2 and low-density N2–CH4 fluid inclusions indicate several stages of tectonic activity and suggest fluid influx from the nearby metapelites. High-
and low-salinity aqueous inclusions observed beside CO2 inclusions in garnet-pyroxene granulites, in vein quartz and shear zones could be of high-grade origin but are mainly re-equilibrated
or re-trapped along healed microfractures during lower-grade stages.
Received: 21 May 1997 / Accepted: 6 October 1997 相似文献
13.
<正>Exploration practices show that the Jurassic System in the hinterland region of the Junggar Basin has a low degree of exploration but huge potential,however the oil/gas accumulation rule is very complicated,and it is difficult to predict hydrocarbon-bearing properties.The research indicates that the oil and gas is controlled by structure facies belt and sedimentary system distribution macroscopically,and hydrocarbon-bearing properties of sand bodies are controlled by lithofacies and petrophysical facies microscopically.Controlled by ancient and current tectonic frameworks,most of the discovered oil and gas are distributed in the delta front sedimentary system of a palaeo-tectonic belt and an ancient slope belt.Subaqueous branch channels and estuary dams mainly with medium and fine sandstone are the main reservoirs and oil production layers,and sand bodies of high porosity and high permeability have good hydrocarbon-bearing properties;the facies controlling effect shows a reservoir controlling geologic model of relatively high porosity and permeability.The hydrocarbon distribution is also controlled by relatively low potential energy at the high points of local structure macroscopically, while most of the successful wells are distributed at the high points of local structure,and the hydrocarbon-bearing property is good at the place of relatively low potential energy;the hydrocarbon distribution is in close connection with faults,and the reservoirs near the fault in the region of relatively low pressure have good oil and gas shows;the distribution of lithologic reservoirs at the depression slope is controlled by the distribution of sand bodies at positions of relatively high porosity and permeability.The formation of the reservoir of the Jurassic in the Junggar Basin shows characteristics of favorable facies and low-potential coupling control,and among the currently discovered reservoirs and industrial hydrocarbon production wells,more than 90%are developed within the scope of faciespotential index FPI0.5,while the FPI and oil saturation of the discovered reservoir and unascertained traps have relatively good linear correlation.By establishing the relation model between hydrocarbonbearing properties of traps and FPI,totally 43 favorable targets are predicted in four main target series of strata and mainly distributed in the Badaowan Formation and the Sangonghe Formation,and the most favorable targets include the north and east of the Shinan Sag,the middle and south of the Mobei Uplift,Cai-35 well area of the Cainan Oilfield,and North-74 well area of the Zhangbei fault-fold zone. 相似文献
14.
Insights into oil cracking based on laboratory experiments 总被引：3，自引：0，他引：3
The objectives of this pyrolysis investigation were to determine changes in (1) oil composition, (2) gas composition and (3) gas carbon isotope ratios and to compare these results with hydrocarbons in reservoirs. Laboratory cracking of a saturate-rich Devonian oil by confined, dry pyrolysis was performed at T=350–450 °C, P=650 bars and times ranging from 24 h to 33 days. Increasing thermal stress results in the C15+ hydrocarbon fraction cracking to form C6–14 and C1–5 hydrocarbons and pyrobitumen. The C6–14 fraction continues to crack to C1–5 gases plus pyrobitumen at higher temperatures and prolonged heating time and the δ 13Cethane–δ13Cpropane difference becomes greater as oil cracking progresses. There is considerable overlap in product generation and product cracking. Oil cracking products accumulate either because the rate of generation of any product is greater than the rate of removal by cracking of that product or because the product is a stable end member under the experimental conditions. Oil cracking products decrease when the amount of product generated from a reactant is less than the amount of product cracked. If pyrolysis gas compositions are representative of gases generated from oil cracking in nature, then understanding the processes that alter natural gas composition is critical. 相似文献
15.
Development of secondary porosity in the Fairholme carbonate complex (southwest Alberta, Canada) 总被引：4，自引：0，他引：4
Veerle Vandeginste Rudy Swennen Sarah A. Gleeson Rob M. Ellam Kirk Osadetz Franois Roure 《Journal of Geochemical Exploration》2006,89(1-3):394
Because of their economic importance as hydrocarbon reservoirs, the Upper Devonian dolomitized carbonate reefs in southwest Alberta have been the subject of several studies. Still, there is no consensus on the process of matrix dolomitization and furthermore, the process of vug development is not often addressed. The studied outcrops show features of an early diagenetic matrix-selective dolomitization by a Late Devonian seawater-derived fluid. Seepage reflux dolomitization combined with latent reflux is proposed, which best explains most chemical characteristics. The cements in the vugs are precipitated from warm saline, 87Sr-enriched fluids and testify to thermogenic sulphate reduction based on the presence of sulphur, CO2 and H2S in inclusions, relatively high homogenization temperatures and depleted δ13C values, which sets constraints on the timing of vug formation. Secondary porosity may be created by the mixing of formation water with a tectonically and topographically driven fluid and by the dissolution of anhydrite nodules. 相似文献
16.
17.
M. Z. Stout M. L. Crawford E. D. Ghent 《Contributions to Mineralogy and Petrology》1986,92(2):236-247
Metamorphosed pelitic rocks from Mica Creek, British Columbia contain sillimanite, kyanite with minor fibrolite and andalusite-bearing quartz pods. Mineral equilibria were used to infer peak P-T conditions and fluid compositions in equilibrium with the solid phases. Fluid inclusions in three schist samples appear to be good indicators of conditions affecting those rocks during and after peak metamorphic conditions. In samples from two localities, fluid inclusions from schist and quartz-rich segregations have densities appropriate to the peak metamorphic conditions. The observed compositions for these fluids (low salinity with 12 mole % dissolved CO2) agree with calculated
values of 0.84 to 0.85, based upon paragonite-quartz-albite-Al2SiO5 equilibria. The fluids unmixed as the schists were uplifted and cooled; fluid inclusions trapped during this stage outline a solvus in the CO2-H2O-NaCl system. A later influx of fluids containing CH4 and N2 accompanied formation of andalusite-bearing plagioclaserich segregations. The restricted association of andalusite-bearing pods and low density fluids suggest a localized but pervasive fluid influx during uplift. Preservation of high density fluid inclusions during uplift and erosion, coupled with evidence for unmixing of H2O- and CO2-rich fluids on the solvus, provide constraints on the P-T uplift path. 相似文献
18.
Fluid inclusions were studied in quartz samples from early (stage I) gold-poor quartz veins and later (stage II) gold- and
sulphide-rich quartz veins from the Wenyu, Dongchuang, Qiangma, and Guijiayu mesothermal gold deposits in the Xiaoqinling
district, China. Fluid inclusion petrography, microthermometry, and bulk gas analyses show remarkably consistent fluid composition
in all studied deposits. Primary inclusions in quartz samples are dominated by mixed CO2-H2O inclusions, which have a wide range in CO2 content and coexist with lesser primary CO2-rich and aqueous inclusions. In addition, a few secondary aqueous inclusions are found along late-healed fractures. Microthermometry
and bulk gas analyses suggest hydrothermal fluids with typically 15–30 mol% CO2 in stage I inclusions and 10–20 mol% CO2 in stage II inclusions. Estimates of fluid salinity decrease from 7.4–9.2 equivalent wt.% NaCl to 5.7–7.4 equivalent wt.%
NaCl between stage I and II. Primary aqueous inclusions in both stages show consistent salinity with, but slightly lower Th
total than, their coexistent CO2-H2O inclusions. The coexisting CO2-rich, CO2-H2O, and primary aqueous inclusions in both stage I and II quartz are interpreted to have been trapped during unmixing of a
homogeneous CO2-H2O parent fluid. The homogenisation temperatures of the primary aqueous inclusions give an estimate of trapping temperature
of the fluids. Trapping conditions are typically 300–370 °C and 2.2 kbar for stage I fluids and 250–320 °C and 1.6 kbar for
stage II fluids. The CO2-H2O stage I and II fluids are probably from a magmatic source, most likely devolatilizing Cretaceous Yanshanian granitoids.
The study demonstrates that gold is largely deposited as pressures and temperatures fall accompanying fluid immiscibility
in stage II veins.
Received: 15 May 1997 / Accepted: 10 June 1998 相似文献
19.
XIE Zengye LI Jian LI Zhisheng GUO Jianying LI Jin ZHANG Lu DONG Caiyuan 《《地质学报》英文版》2017,91(5):1836-1854
The alternative development of coal-bearing hydrocarbon source rocks and low-porosity and low-permeability tight sandstone reservoirs of the Triassic Xujiahe Formation in the Sichuan Basin is favorable for near-source hydrocarbon accumulation. The natural gas composition of the Xujiahe Formation in the Sichuan Basin is dominated by hydrocarbon gases, of which the methane content is80.16%-98.67%. Typically, the C_2~+ content is larger than 5% in main wet gas. The dry gas is mainly distributed in the western and northern regions of the basin. The non-hydrocarbon gases mainly contain nitrogen, carbon dioxide, hydrogen, and helium, with a total content of 2%. The carbon isotope ranges of methane and its homologues in natural gas are: δ~(13)C_1 of-43.8‰ to-29.6‰, δ~(13)C_2 of-35.4‰ to-21.5‰, δ~(13)C_3 of-27.6‰ to-19.8‰,and δ~(13)C_4 of-27.7‰ to-18.8‰. δ~(13)C_3δ~(13)C_4 occurs in some natural gas with a low evolution degree; such gas is mainly coal-related gas from humic-type source rocks of the Xujiahe Formation. As for the natural gas, δ~2 H_(CH4) values ranged from-195‰ to-161‰,δ~2 H_(C2H6) values ranged from-154‰ to-120‰, and δ~2 H_(C3H8) values ranged from-151‰ to-108‰. The dry coefficient,δ~(13)C and δ~2 H_(CH4) are all positively correlated with the maturity of source rocks. The higher the maturity of source rocks is, the larger the natural gas dry coefficient is and the larger the δ~(13)C and δ~2 H_(CH_4) values are, indicative of the characteristic of near-source accumulation. The δ~2 H_(C2H6) value of natural gas is influenced by paleosalinity to a relatively large extent; the higher the paleosalinity is, the larger the δ~2 H_(C2H6) value is. The Pr/Ph value of the condensate oil ranged from 1.60 to 3.43, illustrating light oxidization-light reduction and partial-oxidization characteristics of the depositional environment of coal-bearing source rocks of the Xujiahe Formation. The natural gas light hydrocarbon(C_5-C_7) from the Xujiahe Formation presented two characteristics: the first was the relatively high aromatic hydrocarbon content(19%-32.1%), which reveals the characteristic of natural gas with humic substances of high-maturity; the second was the low content of aromatic hydrocarbon(0.4%-9.3%),reflecting water-washing during the accumulation of the natural gas. The reported research outcomes indicate a potential mechanism for natural gas accumulation in the Xujiahe Formation, which will further guide natural gas exploration in this region. 相似文献
20.
Hydrocarbon—Generating Characteristics of Barkinite—Rich Colas from Late Permian Longtan Formation ,South China 总被引：1，自引：0，他引：1
孙旭光 《中国地球化学学报》2000,19(3):227-232
Leping coal (including barkinite-rich coal) is a unique kind of coal,which is widely distrbuted in the Late Permian Longan Formation,South China,In this paper,ROck-Eval,Py-GC and simulation experiment via an open-system were used to study the hydrocarbon-generating potential,hydrocarbon composition.and hydrocarbon-generating model of barkiniterich coals from the shuicheng coal field of Guizhou Province,Southwest China.The results show that barkinite-rich coals have high hydrocarbon-generating potential,with S1 S2 being 211-311mg/g,and can produce large amounts of hydrocorbon at the high-maturity stage,mostly within the temperature range of 420-450℃(corresponding to VR0 1.1-1.5%);barkinite-rich coal is one of the better oil sources and light hydrocarbon and wet gas are the major hydrocarbon components,which account for 45% and 33% of the total hydrocarbons.respectively.These characteristics are of importance for exploring oil and gas resources in the Late permian Longtan Formation coals,southwest China. 相似文献