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1.
Organic inclusions as an indicator of oil/gas potential assessment of carbonate reservoir beds 总被引：1，自引：0，他引：1
Organic inclusions could be formed at the stages of either primary or secondary migration of hydrocarbons so long as mineral
crystallization or recrystallization takes place in the sediments, presenting a direct indicator of oil/gas evolution, migration
and abundance. Based on the study of organic inclusions in carbonate-type reservoir beds of commercial importance from North
China, Xingjing, North Jiangsu, Jianghan, Sichuan and Guizhou in China, many inclusion parameters for oil/gas potential assessment
of carbonate reservoir beds are summarized in this paper, including: 1) Types of organic inclusion: Commercially important
oil beds are characterized by inclusions consisting of either pure liquid hydrocarbons or liquid plus minor gaseous hydrocarbons,
while commercially important gas reservoirs are characterized by inclusions consisting of either pure gaseous hydrocarbons
or gas plus minor liquid hydrocarbons. 2) Quantity of organic inclusions: The number of organic inclusions in commercially
important oil/gas reservoirs is over 60% of the total inclusion percentage. 3) Temperature of saline inclusions: The homogenization
temperatures of contemporaneous saline inclusions in oil reservoirs range from 91–161 °C, while in gas reservoirs from 150–250
°C). 4) Inclusion composition: In commercially important oil reservoirs, C1/C2=2−10, C1/C3=2−4, C1/C4=2−21, (C2−C4)/(C1−C4)(%)>20, (CH4+CO+H2)/CO2 (molecules/g)=0.5−1.0, and in C2−C3−nC4 triangle diagram there should be an upside-down triangle with the apex within the ellipse, while in commercial gas reservoirs,
C1/C2=10−35, C1/C3=14−82, C1/C4=21−200, (C2−C4)/(C1−C4)(%)<20, (CH4+CO+H2)/CO2>1, and there would be an upright triangle with the apex within the ellipse.
The above-mentioned parameters have been used to evaluate a number of other unknown wells or regions and the results are very
satisfactory. It is valid to use organic inclusions as an indicator to assess the oil/gas potential during oil/gas exploration
and prospecting. This approach is effective, economic, rapid, and easy to popularize. 相似文献
2.
3.
Forty-six crude oil samples were selected from the Ordovician in the northwestern part of the Tahe oilfield for detailed molecular geochemical and isotopic analysis, including group compositions, carbonhydrogen isotopes and gas chroma-tograms of saturated hydrocarbons, as well as the characteristics of terpane, sterane and other biomarkers, indicating that crude oils are of the same origin from different districts in the Tahe oilfield and were derived from the same source kitchen (or oil source formation), i.e., mainly stemming from marine hydrocarbons. Detailed studies of oil physical properties of 25-honpane revealed that such oils have heavy or thick oil qualities due to biodegradation. Comprehensive assessment in terms of five maturity parameters shows that the oils from the Ordovician with Ro values varying from 0.80% to 1.59% are widely distributed in the northwest of the Tahe oilfield. 相似文献
4.
Bicyclic sesquiterpenoids are mostly used to illustrate the origins of organic matter and genetic types of crude oil presently.In this paper,the relationship between distributions and compositions of C16 homodrimane in immature to mature source rocks and evolution of organic matter was studied,and the correlation between C16 homodrimane at immature to low mature stages and thermal evolution of organic matter was analyzed.The results show that in terrestrial facies depositional system,the ratio of 8α(H)-homodrimane to 8β(H)-homodrimane has a high sensitivity about the maturity’s minor changes at immature to low mature stages.It is found that when the vitrinite reflectance R0<0.7%,the ratio significantly decreases with increasing burial depth or maturity.This kind of phenomenon reveals that these parameters may be the useful maturity indicators for determining the relative maturation of organic matter at immature to low mature stages,and have certain practical value in biogeochemical and en- vironmental geochemical research on low mature oil and gas. 相似文献
5.
The Jurassic coals of the Junggar and Turpan-Hami basins, Xinjiang, China, are characterized by abundant vitrinite. Microscopic
analysis of Junggar coal samples indicates that they contain desmocollinite and hydrogen-rich vitrinite with a low reflectivity.
The hydrocarbon-generating potential of various macerais follows the decreasing order of exinite > vitrinite > inertinite.
However, desmocollinite is a principal maceral for hydrocarbon generation in this area because the content of vitrinite is
higher than that of exinite. Data from simulating experiments and infrared spectra show that the hydrocarbon-generating process
occurred primarily at the lower-mature stage in the Middle-Lower Jurassic coal measures. Generally, crude oil from the Qigu
oilfield has a close similarity in hopanoid distribution to the vitrinite and exinite from the Jurassic strata with C23-C32 pentacyclic triterpanes and γ-lupane being present. The distribution of steranes is also similar. C29-sitostane is dominant and Q27 ergostane is subordinate. Only a trace amount of cholestane is present. All this suggests that the crude oil from the Qigu
oilfield was derived from Jurassic coal measures. 相似文献
6.
OILFIELDWATER,WHICHEXISTSCONCOMITANTLYWITH OILORGASINSUBSURFACERESERVOIRS,ISAKINDOFIMPOR TANTCOMPONENTOFRESERVOIRFLUIDANDALSOISADRIVING FORCEANDCARRIERFORHYDROCARBONMIGRATION,ACCUMULA TIONANDHYDROCARBONRESERVOIRFORMATION.OILFIELDWA TER,HYDROCARBONANDRESER… 相似文献
7.
Basalts interbedded with oil source rocks are discovered frequently in rift basins of eastern China, where CO2 is found in reservoirs around or within basalts, for example in the Binnan reservoir of the Dongying Depression. In the reservoirs, CO2 with heavy carbon isotopic composition (δ13C>-10‰ PDB) is in most cases accounts for 40% of the total gas reserve, and is believed to have resulted from degassing of basaltic magma from the mantle. In their investigations of the Binnan reservoir, the authors suggested that the CO2 would result from interactions between the source rocks and basalts. As the source rocks around basalts are rich in carbonate minerals, volcanic minerals, transition metals and organic matter, during their burial history some of the transition metals were catalyzed on the thermal degradation of organic matter into hydrocarbons and on the decomposition of carbonate minerals into CO2, which was reproduced in thermal simulations of the source rocks with the transition metals (Ni and Co). This kind of CO2 accounts for 55%-85% of the total gas reserve generated in the process of thermal simulation, and its δ13C values range from -11‰- -7.2‰ PDB, which are very similar to those of CO2 found in the Binnan reservoir. The co-generation of CO2 and hydrocarbon gases makes it possible their accumulation together in one trap. In other words, if the CO2 resulted directly from degassing of basaltic magma or was derived from the mantle, it could not be accumulated with hydrocarbon gases because it came into the basin much earlier than hydrocarbon generation and much earlier than trap formation. Therefore, the source rocks around basalts generated hydrocarbons and CO2 simultaneously through catalysis of Co and Ni transition metals, which is useful for the explanation of co-accumulation of hydrocarbon gases and CO2 in rift basins in eastern China. 相似文献
8.
Yang Tao Jiang Shaoyong Ge Lu Yang Jinghong Ling Hongfei Wu Nengyou Zhang Guangxue Liu Jian Chen Daohua 《Frontiers of Earth Science》2007,1(2):212-217
Gas hydrate is a recently-found new source of energy that mostly exists in marine sediments. In recent years, we have conducted
gas hydrate exploration in the South China Sea. The Xisha trough, one of the promising target areas for gas hydrate, is located
in the northern margin of the South China Sea, adjacent to several large oil and gas fields. The Xisha trough extends 420
km long with the water depth of 1 500 m in the west part and 3 400 m in the east part and deposits thick sediments with organic
matter content of 0.41%–1.02%. Previous studies on topographical features, geological P-T conditions, structural geology,
sedimentary geology and geophysical bottom simulating reflectors (BSR) in the Xisha trough suggest that this area is favorable
for the formation and accumulation of gas hydrate. In this paper, we present geochemical analyses for the sediment and pore
water from a piston core at Site XS-01 in the Xisha trough. Seven pore water samples were analyzed for their anion (Cl−, SO4
2−, Br−, I−) contents, cation (Na, K, Ca, Mg) contents and trace element (Li, B, Sr, Ba, Rb, Mn) contents. Eight sediment samples were
analyzed for stable carbon and oxygen isotopic compositions. A number of geochemical anomalies such as anions (e.g. Cl−, SO4
2−), cations (e.g. Ca, Mg) and trace elements (e.g. Sr, Ba, B) were found in this study. For example, the concentrations of
Cl− and SO4
2− in pore water show a decreasing trend with depth. The estimated sulfate/methane interface (SMI) is only 18 m, which is quite
similar to the SMI value of 23 m in the ODP164 Leg 997 at Blake Ridge. The Ca, Mg and Sr concentrations of pore water also
decrease with depth, but concentrations of Ba, and Mg/Ca and Sr/Ca ratios increase with depth. These geochemical anomalies
are quite similar to those found in gas hydrate locations in the world such as the Blake Ridge and may be related to the formation
and dissociation of gas hydrates. The salt exclusion effect during the gas hydrate formation will cause an increase in major
ion concentrations in the pore waters that diffused upward such as Cl. The anaerobic methane oxidation (AMO) may lead to the
change of SO4
2− and other cations such as Ca, Mg, Sr and Ba in pore water. Low δ
13C value of authigenic carbonates is a good indicator for gas hydrate occurrence. However, the bulk sediment samples we analyzed
all show normal δ
13C values similar to biogenic marine carbonates, and this may also suggest that no gas hydrate-related authigenic carbonates
exist or their amount is so small that they are not detectable by using this bulk analytical method. In conclusion, we suggest
that the Site XS-01 in the Xisha trough of the northern margin of the South China Sea is a potential target for further gas
hydrate exploration.
Translated from Quaternary Sciences, 2006, 26(3): 442–448 [译自: 第四纪研究] 相似文献
9.
This paper presents data on the inorganic geochemical characteristics of the sediments from Hole LZ1024 (Lake El’gygytgyn,
Chukotka, 67°30′ N 172°08′ E). It is demonstrated how these data are associated with climatic variations during isotope stages
1–9. The sediments of the warm stages are characterized by elevated contents of SiO2, CaO, Na2O, K2O, and Sr and low concentrations of TiO2, Al2O3, MgO, and Fe2O3. It has been established that the geochemical parameters correlate with global climatic variations. 相似文献
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11.
The absolute amounts and relative distributions of neutral nitrogen compounds in the Tabei oilfield (e. G. Blocks Ln1-Ln1 1) showed remarkable migration fractionation in the vertical direction. From Ordovician reservoirs (O) to oil legs TⅢ and T Ⅰ of Triassic reservoirs in blocks LN1-LN11, the concentrations of [a] [c] decreased from 1. 59μg/g, 0.49μg/g to 0.17 μg/g (oil). The ratios of various alkylcarbazole isomers, such as 1,8-dimethylcarbazole/nitrogenpartially shielded isomers and 1,8-dimethylcarbazole/nitrogen-exposed isomers, were adopted as the indicators of petroleum migration. The ratios increased from 0.13, 0.20 to 0.67 and from going from the south to the north of the Tabei oilfield, the absolute concentrations of neutral nitrogen compounds decreased drastically, and the nitrogen-shielded isomers were enriched relative to nitrogen-exposed isomers and nitrogen-partially shielded isomers. Crude oils in the Tabei oilfield migrated laterally from the Jilake structure to the Sangtamu fault uplift and Lunnan fault uplift, and crude oils in the same fault uplift migrated and remigrated vertically from Ordovician reservoirs, to oil legs TⅢ to TⅠ of Triassic reservoirs. 相似文献
12.
Aleksra ?AJNOVI? Vladimir SIMI? Branimir JOVAN?I?EVI? Olga CVETKOVI? Radovan DIMITRIJEVI? Nenad GRUBIN 《《地质学报》英文版》2008,82(6):1201-1212
Sediments of the western part of the Valjevo-Mionica basin （Serbia） were examined both geochemically and mineralogically to explain, on the basis of their sedimentologicai characteristics, the causes of changes in their qualitative and quantitative composition. A total of 62 samples obtained from the drillhole at depths up to 400 m was investigated. Using correlation of the obtained data, six geochemical zones were defined, two of which being specially distinguished by their mineralogical, geochemical and sedimentological characteristics. The first one, upper zone A, consists of banded marlstones interbedded with clay and oil shales and is characterized by presence of analcite and searlesite. These minerals and very high contents of Na20 indicate sedimentation in alkaline conditions with increased salinity in arid climate. That provided pronounced water stratification, as well as higher bioproductivity in the basin and sedimentary organic matter preservation. Therefore, the zone A sediments are characterized by high organic matter contents of the type which provides good potential for production of liquid hydrocarbons. Another specific zone, zone F, contains sediments with very high MgO, K2O and Li concentrations. Their geochemical correlation, as well as almost complete absence of illite in this zone, indicates the presence of interstratified clay mineral type illite-saponite （lithium-bearing Mg-smectite）. 相似文献
13.
Salvatore Giammanco Barbara Justin Natalija Speh Marta Veder 《Environmental Geology》2009,57(1):75-89
The complex geochemical interactions in the groundwater of the industrial area of Šalek Valley (Slovenia) between natural
and anthropogenic fluids were studied by means of major (Ca, Mg, Na, K, HCO3
−, Cl− and SO4
2−) and trace elements’ (As , Cd, Cu, Pb, Zn, Hg, Se and V) abundances, geochemical classification and statistical analysis
of data. Cation abundances indicate mixing between a dolomitic end-member and an evaporitic or geothermal end-member. Anion
abundances indicate mixing between bicarbonate waters and either sulphate-enriched waters (suggesting hydrothermalism) or
chlorine-rich waters. Principal component analysis (PCA) allowed the extraction of seven factors, which describe, respectively:
water–rock interaction mainly on dolomitic rocks; redox conditions of water; Cd–Zn enrichment in chlorine-rich waters (probably
from industrial wastes); hydrothermal conditions in waters close to major faults; Pb and Cu pollution; V and K enrichments,
indicating their common organic source; the role of partial pressure of CO2 dissolved in water, which is highest in three wells with bubbling gases. Average underground discharge rates of solutes from
the Valley range between 0.09 t/a (V) and 1.8 × 104 t/a (HCO3
−) and indicate how natural fluids can significantly contribute to the levels of elements in the environment, in addition to
the amount of elements released by human activities. 相似文献
14.
15.
With wells Puguang 2 and 6 in the Puguang gas field as the research objects by choosing organic carbon as characterization reservoir carbon(indirectly reflecting the bitumen contents),this paper discusses the relationship between bitumen contents and lithologic characteristics,reservoir characteristics,and calculates the volume of paleo-oil and oil cracked gas.The study shows that the organic carbon contents of the reservoirs are related to lithologic characteristics.Due to variations in the particle size or structure of rocks,the porosity of the reservoirs varies,furthermore,it will influence the contents of organic carbon.And the relationship between these two parameters is positive.Based on the analysis,the relationship between total organic carbon(TOC)and the contents of reservoir bitumen also appears to be positive.The volume of paleo-oil and cracked gas of the Changxing-Feixian’guan Formation are respectively 495 million tons and 360.4 billion m3 through the calculation of reservoir’s organic carbon.Therefore,the relationship between carbon-bearing rate and characteristics of the reservoirs can be used to indirectly evaluate reservoir types.Besides,the carbon-bearing rate of the reservoirs also reflects the contents of reservoir bitumen,paleo-oil as well as natural gas.It makes a new approach for the study of the types of reservoirs and the amounts of paleo-oil and oil cracked gas in northeastern Sichuan Basin. 相似文献
16.
In this study, reservoir temperatures of Balıkesir geothermal waters in northwestern Turkey are estimated with various geochemical
models. The geothermal fluids in the region are represented by Na–SO4, Na–HCO3 and Ca–HCO3 type waters with discharge temperatures up to 98°C. It was determined that the solubility of silica in most of the waters
is controlled by the chalcedony phase. Equilibrium states of the Balıkesir thermal waters studied by means of Na–K–Mg–Ca diagram,
mineral saturation calculations and activity diagrams in the system composed of Na2O–CaO–K2O–Al2O3–SiO2–H2O phases approximate a reservoir temperature of about 120°C. Most of the waters are found to be equilibrated with calcite,
chalcedony ± quartz and muscovite at predicted temperature ranges, similar to those calculated from the chemical geothermometers. 相似文献
17.
油气化探利用地球化学方法寻找油气,具有直接、快速、有效、成本低的特点,已在油气勘探实践中取得了较好的效果,并在一定时期得到了较为广泛的应用。但油气化探作为一门新兴学科,在许多方面仍存在不足,其中异常的稳定性与重现性是制约油气化探推广应用的认识障碍。以河南泌阳洼陷（井楼-古城油田）和山东临邑洼陷南斜坡（临南油田）的实际地球化学测量资料为基础,通过已知油气藏上方不同期次（同年）、不同时期的油气化探异常特征的对比,从油气化探指标组合关系、结构特征、剖面显示、油气异常的平面分布等方面证实油气化探异常存在较好的稳定性,表明利用油气化探技术方法寻找油气是可行的,并进一步证实了油气化探在油气勘探中的应用前景。 相似文献
18.
Y.K. Kharaka A.S. Maest W.W. Carothers L.M. Law P.J. Lamothe T.L. Fries 《Applied Geochemistry》1987,2(5-6)
Oil-field brines are the most favored ore-forming solutions for the sediment-hosted Mississippi Valley-type ore deposits. Detailed inorganic and organic chemical and isotope analyses of water and gas samples from six oil fields in central Mississippi, one of the very few areas with high metal brines, were conducted to study the inorganic and organic complexes responsible for the high concentrations of these metals. The samples were obtained from production zones consisting of sandstone and limestone that range in depth from 1900 to 4000 m (70–120°C) and in age from Late Cretaceous to Late Jurassic. Results show that the waters are dominantly bittern brines related to the Louann Salt. The brines have extremely high salinities that range from 160,000 to 320,000 mg/l total dissolved solids and are NaCaCl-type waters with very high concentrations of Ca (up to 48,000 mg/l) and other alkaline-earth metals, but with low concentrations of aliphatic acid anions. The concentrations of metals in many water samples are very high, reaching values of 70 mg/l for Pb, 245 mg/l for Zn, 465 mg/l for Fe and 210 mg/l for Mn. The samples with high metal contents have extremely low concentrations (<0.02 mg/l) of H2S. Samples obtained from the Smackover Formation (limestone) have low metal contents that are more typical of oil-field waters, but have very high concentrations (up to 85 mg/l) of H2S. Computations with the geochemical code SOLMINEQ.87 give the following results: (1) both Pb and Zn are present predominantly as aqueous chloride complexes (mainly as PbCl42− and ZnCl42−, respectively); (2) the concentrations of metals complexed with short-chained aliphatic acid anions and reduced S species are minor; (3) organic acid anions are important in controlling the concentrations of metals because they affect the pH and buffer capacity of the waters at subsurface conditions; and (4) galena and sphalerite solubilities control the concentrations of Pb and Zn in these waters. 相似文献
19.
Middle–Lower Jurassic terrigenous shales constitute a set of significant hydrocarbon source rocks in the Kuqa Depression of the Tarim Basin. Until recently, however, most investigations regarding this set of hydrocarbon source rocks have mainly focused on conventional oil and gas reservoirs, and little research has been conducted on the formation conditions of shale gases. This research, which is based on core samples from nine wells in the Kuqa Depression, investigated the geological, geochemical, mineralogical and porosity characteristics of the shales, analysed the geological and geochemical conditions for the formation of shale gases, and evaluated the shale gas resource potential. The results show that the distribution of the Middle–Lower Jurassic shales is broad, with thicknesses reaching up to 300–500 km. The total organic carbon (TOC) content is relatively high, ranging from 0.2 to 13.5 wt% with a mean of 2.7 wt%. The remaining hydrocarbon generative potential is between 0.1 and 22.34 mg/g, with a large range of variation and a mean value of 3.98 mg/g. It is dominated by type III kerogen with the presence of minor type II1 kerogen. The vitrinite reflectance values range from 0.517 to 1.572%, indicating the shales are in a mature or highly mature stage. The shales are mainly composed of quartz (19–76%), clay (18–68%) and plagioclase (1–10%) with mean contents of 50.36 wt%, 41.42 wt%, and 3.37 wt%, respectively. The pore spaces are completely dominated by primary porosity, secondary porosity and microfractures. The porosity is less than 10% and is mainly between 0.5 and 4%, and the permeability is generally less than 0.1 mD. These results classify the shale as a low-porosity and ultra-low-permeability reservoir. The porosity has no obvious correlation with the brittle or clay mineral contents, but it is significantly positively correlated with the TOC content. The maximum adsorbed gas content is between 0.82 and 8.52 m3/t with a mean of 3.37 m3/t. In general, the shale gas adsorption content increases with increasing the TOC content, especially when the TOC content is greater than 1.0%. The volumetric method, used to calculate the geological resources of the Middle–Lower Jurassic shales in the Kuqa Depression, shows that the geological resources of the Middle and Lower Jurassic shales reach 667.681 and 988.115 × 109 m3, respectively with good conditions for the formation of shale gas and good prospects for shale gas exploration. 相似文献
20.
青海柴达木盆地南八仙油气田油源与成藏机理 总被引：12，自引：1，他引：11
柴达木盆地南八仙油气田不同油气藏间原油性质特征变化明显,油层在纵向井段上分布范围逾3000余m。通过地球化学实验并结合构造等地质条件分析,认为该区各种深、浅层油气藏中的原油具有煤成烃的基本地球化学特征,并且为同一来源,油源为临近地区较深部位中侏罗统煤系地层;该区深、浅层原油物性间的差异也反映在地球化学指标上,其成因或成藏机理是：深部早期油藏在断裂等地质作用下发生了明显的蒸发分馏作用,其分馏出的产物在浅部再次聚集成藏。 相似文献