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1.
Organic geochemical evaluation of thirty-two Aptian to Campanian shale samples from seven wells drilled on the shelf of the Orange Basin (southwestern Atlantic margin) was carried out in order to determine their origin, depositional environment, thermal maturity and hydrocarbon potential. The shale samples, selected to represent highstand, lowstand and transgressive systems tracts, were analysed by Rock–Eval pyrolysis for total organic C characteristics and by gas chromatography (GC) and gas chromatography–mass spectrometry (GC–MS) for n-alkanes, aliphatic isoprenoid hydrocarbons and biomarkers (steranes, hopanes and tricylic terpanes). For most of the shale samples Rock–Eval data, hydrogen (HI) and oxygen index (OI) point to mainly Type III terrigenous organic matter. Only a few samples of Turonian age reveal a higher proportion of marine organic matter being classified as Type II/III or Type II. Biomarker parameters suggest that the samples are deposited under suboxic to oxic environmental conditions. Rock–Eval data and biomarker maturity parameters assign for most of the samples a maturity level at the beginning of the oil window with some more mature samples of Aptian, Albian and Cenomanian age. The hydrocarbon generation potential is low for most of the shelf shales as indicated by the S2/S3 ratio and HI values. Exceptions are some samples of Turonian and Aptian age. 相似文献
2.
Benzene extractable aliphatic hydrocarbons from the New Albany Shale in the Illinois Basin were characterized by gas chromatography and mass spectrometry, and the total organic matter of the shale was characterized by solid state carbon-13 cross polarization magic angle spinning nuclear magnetic resonance. Core samples from a northwest-trending cross-section of the Illinois Basin were studied. Gas chromatography (GC) and gas chromatography-mass spectrometric analysis (GC/MS) data indicate a regional variation of the aliphatic composition of the shale extracts. A positive, linear relationship between the two ratios, pristane/n-C17 and phytane/n-C18, is indicated. The NMR results indicated that organic matter deposited in northwestern Illinois shale is relatively high in aliphatic hydrocarbon content while, in contrast, organic matter found in southeastern Illinois shale is relatively low in aliphatic hydrocarbon content. Our findings suggest that the organic variation of the shale is mainly due to the differences in thermal maturity of the shale organic matter and the use of pristane/n-C17 ratio as a thermal parameter in the study of oil may be extended to the study of the ancient sediments. 相似文献
3.
The purpose of the study is to better understand the relationship between organic matter optical properties and the presence of potentially large oil and gas accumulations in Arctic Canada. The type and thermal maturity of the dispersed organic matter of the Mesozoic formations in the southern Sverdrup Basin, Melville Island, have been studied using organic petrology and Rock-Eval pyrolysis.All types of organic matter are present in the strata of Mesozoic age. Hydrogen-rich liptinite is dominated by alginite (Botryococcus and Tasmanites), dinoflagellate cysts and amorphous fluorescing matrix. Sporinite, cutinite, resinite and liptodetrinite made up the lesser hydrogen-rich exinite. Vitrinite reflectance in Cretaceous sediments ranges from 0.36 to 0.65% Ro; in Jurassic sediments it ranges from 0.40 to 1.0% Ro and in the Triassic from 0.45 to 1.30% Ro, showing an overall increase with depth of burial.Cretaceous sediments of the Deer Bay Formation are thermally immature and contain organic matter of terrestrial origin. The Upper Jurassic shales of the Ringnes Formation contain predominantly organic matter of liptinitic and exinitic origin with a considerable vitrinitic input. At optimum maturation levels, potential source beds of this formation would have a good hydrocarbon-generating potential. The hydrocarbon potential, however, would be limited to the generation of gases due to the leanness of the source rocks. Parts of the Lower Jurassic Jameson Bay Formation are organic-rich and contain a mixed exinitic/vitrinitic organic matter, Botryococcus colonial algae but visible organic matter is dominated by high plant remains (mainly spores). The Schei Point Group shales and siltstones contain organic matter of almost purely marine origin, whereas the predominantly higher plant-derived organic matter found in the Deer Bay, Jameson Bay and partly in the Ringnes formations have higher TOC. Among the Schei Point Group samples, the Cape Richards and Eden Bay members of the Hoyle Bay Formation are richer in TOC (>2.0%) than the Murray Harbour Formation (Cape Caledonia Member). This may reflect differences in the level of maturity or in the depositional environment (more anoxic conditions for the former).Regional variations in the level of thermal maturity of Mesozoic sediments in Sverdrup Basin appear to be a function of burial depth. The Mesozoic formations thicken towards the basin centre (NNE direction), reflecting the general pattern of increasing thermal maturity north of Sabine Peninsula. However, the regional thermal-maturation pattern of the Mesozoic is not solely a reflection of the present-day geothermal gradient, which indicates that anomalous zones of high geothermal gradient may have existed in the past, at least since when the Mesozoic sediments attained maximum burial depth. The contour pattern of the regional variation of maturity at the base of numerous Triassic formations is similar to that of the structural contours of the Sverdrup Basin, indicating that present-day maturation levels are largely controlled by basin subsidence. 相似文献
4.
The source of the oil at Norman Wells has long been assumed to have been the Canol Formation and/or the Bluefish Member of the Hare Indian Formation. These two units are stratigraphically above and below the Kee Scarp Formation reservoir unit respectively, and are both bituminous shales. A wide range of analytical techniques including Rock-Eval pyrolysis, solvent extraction and fractionation, capillary gas chromatography, gas chromatography-mass spectrometry, and white light and fluorescence microscopy has been used to characterize core samples of these two units and two samples of crude oil from the Norman Wells field.Most of the analytical techniques were insufficiently refined to either differentiate the extracts from each other or to make a definitive oil/source rock correlation. Collision activated decomposition coupled with multiple ion detection mass spectrometry (GC-MS-MS) did provide sufficient chemical compositional detail of the oils and the two potential sources to demonstrate that the Canol Formation has been the effective source of the Norman Wells oil whereas the Bluefish Member has not. Petrological analysis of the organic fractions also indicates that although the bulk organic composition of both units may be classified as Type II organic matter, significant differences exist between them. The Bluefish Member contains substantial amounts of megaspores, whereas the organic matter in the Canol Formation is largely phytoplankton debris.The level of thermal maturity of the core samples ranges from immature to moderately mature in the vicinity of the Norman Wells field to overmature for the samples obtained to the west and north of the field. The level of thermal maturity of the oil was observed to be somewhat higher than that of the samples of the source formation directly above the field. It was thus inferred that some lateral migration from more mature areas has occurred but the extent of this migration was not necessarily more than a few to tens of kilometers. 相似文献
5.
The erosion of rocks rich in organic matter typically leads to the complete mineralization of the organic material. However, in some cases, it is re-deposited to become a part of sediments once more. This process should be considered to be a part of global carbon cycle, possibly much more significant than assumed to-date. The research presented here aims to characterize re-worked organic matter occurring in post-glacial sediments of southern part of Poland, in the Oder river valley (the Racibórz town region, Miocene, Pleistocene and Holocene age). Organic substances extracted from the sediments originated from organic matter that had resided in rocks eroded by glaciers. Sediments were sampled in two boreholes which sediments were correlated. Sediments were extracted and extracts analyzed with gas chromatography-mass spectrometry (GC-MS) to assess distributions of biomarker groups. Organic matter of selected samples was pre-concentrated and analyzed with Py/GC-MS. In the extracts several biomarker parameters of source/environment and thermal maturity were calculated. Organic substances in the investigated sediments come from variable re-deposited organic matter occurring in rocks eroded by glaciers. Three main parent types of re-deposited organic material are identified showing variable geochemical features: 1) organic matter of recent or almost recent age being the source of polar labile compounds; probably formed in situ, 2) re-deposited organic matter of the middle diagenesis showing features similar to lignites (huminite reflectance Rf ~ 0.25–0.35%) deriving from angiosperm remains, mainly monocotyledons and to the lower extend also deciduous trees, 3) re-deposited organic matter at the middle catagenesis (Rf ~ 0.65–0.75%) being the source of most of aromatic hydrocarbons and biomarkers such as steranes, hopanes of the more thermally advanced distribution type. Its geochemical properties and assumed directions of sediment transport indicate bituminous coals of Upper Silesian Coal Basin together with coaly shales as a possible source of this organic matter. Such mixed origin of organic matter caused large discrepancies in values of thermal maturity parameters depending on input from the particular sources and occurrence both geochemical biomarkers and their biochemical precursors in the same samples. 相似文献
6.
富有机质泥页岩纳米级孔隙结构特征研究进展 总被引：6，自引：5，他引：1
阐明富有机质泥页岩孔隙结构特征对阐明页岩油气的赋存机理和勘探开发具有重要的意义。研究泥页岩孔隙结构特征的方法主要包括定量和定性两类,实际研究中常将二者结合使用。有机质含量（TOC）、热演化程度、有机质母质来源、矿物组成及构造变形作用等因素对富有机质泥页岩孔隙结构特征有重要影响。有机质母质来源决定了纳米有机质孔的发育潜能,TOC和矿物组成控制了孔隙的发育类型,而热演化程度决定了孔隙的演化行为,构造变形作用对于纳米孔有后期改造作用。生排烃热模拟实验由于可以人为地控制实验条件,在泥页岩孔隙结构演化研究中扮演了重要的角色,但要注意与实际地质条件相匹配。目前,富有机质泥页岩孔隙结构的演化模式还存在较大的争议。受控于有机质母质来源,不同沉积环境下发育的富有机质泥页岩孔隙结构演化模式存在差异,因此需要分别研究。在未来工作中,TOC对泥页岩孔隙结构特征的影响、有机质孔开始形成的成熟度以及高演化阶段（镜质体反射率Ro>3%）孔隙的演化行为及机理等问题都需要进一步探究。另外,扫描电镜下识别有机质显微组成的方法亟需建立,同时还要规范行业术语的应用,以减少学科研究的混乱现象。 相似文献
7.
Twenty organic rich outcrop samples from the Belait and Setap Shale formations in the Klias Peninsula area, West Sabah, were analysed by means of organic petrology and geochemical techniques. The aims of this study are to assess the type of organic matter, thermal maturity and established source rock characterization based primarily on Rock-Eval pyrolysis data. The shales of the Setap Shale Formation have TOC values varying from 0.6 wt%–1.54 wt% with a mean hydrogen index (HI) of 60.1 mg/g, whereas the shal... 相似文献
8.
J. L. Liu Z. Li M. H. Chang S. Wang L. Chen 《Australian Journal of Earth Sciences》2020,67(3):411-424
AbstractSmall- and medium-sized basins are widely distributed, and some contain commercial gas reservoirs demonstrating their gas-generation potential. The Xuanhua Basin, which is a small-sized coal-bearing basin in north China, includes a promising target for shale-gas exploration in the Xiahuayuan Formation. In this study, we used this basin as a case study to assess the critical geochemical features for small or medium-sized basins to form commercial gas reservoirs. Total organic carbon (TOC) analysis, Rock-Eval pyrolysis, microscopic observation of macerals, vitrinite reflectance measurement and kerogen stable carbon isotope analysis were performed to characterise the organic geochemistry of the Xiahuayuan shales. The original total organic carbon (TOCo) content and hydrocarbon-generative potential (S2o) were reconstructed to further evaluate the gas-generation potential of these shales. In addition, geochemical data of shales from other similar-sized basins with gas discoveries were compared. The results showed that the kerogen from the Xiahuayuan Formation is Type III (gas-prone), and macerals are dominated by vitrinite. TOC values showed a strong heterogeneity in the vertical profiles, with most higher than 1.5?wt%. The measured Ro values ranged from 1.4 to 2.0%. However, thermal maturity was not correlated with the present-day burial depth with higher maturity in the wells closest to the diabase intrusion centre. The remaining generation potential (S2) averaged 0.91?mg HC/g rock, equal to 1.4?cm3 CH4/g rock, and the average amount of hydrocarbon generated was 4.33?cm3 CH4/g rock. In small and medium-sized basins, the TOC content of commercially developed gas shales ranged from 0.5 to 2.5?wt%, organic matter was mainly humic (gas-prone), and the burial depth was generally shallow. Biogenic gas reservoirs for commercial exploitation tend to have larger shale thicknesses (120–800?m) than thermogenic gas reservoirs (60–90?m).
The Xiahuayuan Formation is a good gas-source rock with gas-prone kerogen type, relatively high TOC values and moderate thermal maturity.
The average amount of hydrocarbon generated from the Xiahuayuan shales is about 4.33?cm3 CH4/g rock, indicating a potential to form a shale gas reservoir.
Owing to the influence of diabase intrusions, the Xiahuayuan shales have entered the dry gas window at relatively shallow-buried depths.
Small- and medium-sized basins have the potential to generate commercial gas reservoirs with the generated volume mainly a product of the thickness and maturity of black shales.
9.
渝东南渝页1井下志留统龙马溪组页岩孔隙特征及其主控因素 总被引：2，自引：0，他引：2
富有机质黑色页岩的孔隙结构控制了页岩气的赋存状态和储气量。中国南方地区下志留统是页岩气发育的最重要层位之一。为研究页岩的孔隙特征及其主控因素,对以下志留统龙马溪组页岩气为勘探目标的渝页1井的岩心进行系统的采样,并进行了比表面和孔径、有机质成熟度(Ro)、显微组分、总有机碳(TOC)含量、全岩X射线衍射和粘土矿物含量等一系列分析测试。结果显示,黑色页岩的孔径主要分布于2~5 nm,即以中孔隙为主;中孔体积占总体积的70%左右,微孔体积和宏孔体积分别占10%和20%左右。页岩孔隙结构(微孔体积、中孔体积和宏孔体积)和组成(碎屑矿物成分、粘土矿物成分、TOC和Ro)的相关关系分析表明：粘土矿物对微孔体积和中孔体积都具有控制作用,并且对中孔体积的控制作用更加显著;陆源碎屑含量的增加有利于宏孔体积的增加;有机质成熟度较高时和高成熟度有机碳含量都与宏孔隙体积呈正相关,这可能与高成熟有机质中nm级显微裂缝的发育导致宏孔体积增加有关。 相似文献
10.
Manzur Ahmed Herbert Volk Simon C. George Mohinudeen Faiz Linda Stalker 《Organic Geochemistry》2009,40(7):810-831
Organic geochemical and petrological assessment of coals/coaly shales and fine grained sediments, coupled with organic geochemical analyses of oil samples, all from Permo–Triassic sections of the Southern Sydney Basin (Australia), have enabled identification of the source for the widely distributed oil shows and oil seeps in this region. The Permian coals have higher hydrogen indices, higher liptinite contents, and much higher total organic matter extract yields than the fine grained sediments. A variety of source specific parameters obtained from n-alkanes, regular isoprenoids, terpanes, steranes and diasteranes indicate that the oil shows and seeps were generated and expelled predominantly from higher plant derived organic matter deposited in oxic environments. The source and maturity related biomarkers and aromatic hydrocarbon distributions of the oils are similar to those of the coals. The oil-coal relationship also is demonstrated by similarities in the carbon isotopic composition of the total oils, coal extracts, and their individual n-alkanes. Extracts from the Permo–Triassic fine grained sediments, on the other hand, have organic geochemical signatures indicative of mixed terrestrial and prokaryotic organic matter deposited in suboxic environments, which are significantly different from both the oils and coal extracts. The molecular signatures indicating the presence of prokaryotic organic matter in some of the coal extracts and oils may be due to thin sections of possibly calcareous lithologies interbedded within the coal measures. The genetic relationship between the oils and coals provides new evidence for the generation and expulsion of oils from the Permian coals and raises the possibility for commercial oil accumulations in the Permian and Early Triassic sandstones, potentially in the deeper offshore part of the Sydney Basin. 相似文献
11.
对可可西里中新统五道梁群油页岩研究表明：油页岩有机质丰度中等一高;有机质类型以腐泥型（Ⅰ）-腐殖腐泥型（Ⅱ,）为主。有机质的热演化以低成熟为主;总体上为较好的烃源岩,中新世时可可西里盆地为封闭、干热的以碳酸盐岩沉积为主的盐湖盆地。封闭与还原性静水环境为有机质的堆积和转化形成油页岩提供了条件。 相似文献
12.
《International Geology Review》2012,54(10):1225-1226
Thermal karst, exposed in mine shafts, has been significantly developed in the commercial stratum of oil shales. Geochemical investigations in this karst have for the first time established the secondary changes in the kerogen of the oil shales, namely, an anomalous content of bituminoid A + C, the presence of processes of aromatization, the significant amount of hydrocarbon compounds and humic acids, and changes in the elemental composition of the residual organic matter (in particular, an increase in the C/H ratio). The secondary changes suggest that a favorable geochemical and thermobaric environment existed in the thermal karst for intense bitumen formation. The results obtained are of interest in the study of the kerogen of oil shales as a possible parental source for oil and gas. —Authors. 相似文献
13.
Md. Farhaduzzaman Wan Hasiah Abdullah Md. Aminul Islam 《Journal of the Geological Society of India》2014,83(4):433-446
Surma Group is the most important geological unit of Bengal basin, Bangladesh, because petroleum resources occur within this group. It is mainly composed of alternation of shale and sandstone and the shale fraction has long been considered as source rocks and the sandstone fraction as reservoir. These source and reservoir rocks have been studied by different authors by different approach but none of them adopted organic geochemistry and organic petrology as a means of study of source rock and their possible depositional environment. A total of thirty shale core samples have been collected from eight different gas fields to fulfill the short coming. The collected samples have been subjected to Source Rock Analysis (SRA) and/or Rock-Eval (RE) followed by pyrolysis gas chromatography (PyGC), gas chromatography mass spectrometry (GCMS), elemental analysis (EA) and organic petrological study such as vitrinite reflectance measurement and maceral analysis. The analyzed organic matter extracted from the shales of Surma Group consists mainly of Type III along with some Type II kerogen. The studied shales are mostly organically lean (TOC ±1%) and the extracted organic matter is fair to moderate. Based on these results, the analyzed shales have been ranked as poor (mostly) to fair quality source rock. The organic matter of the analyzed shale samples is thermally immature to early mature for hydrocarbon generation considering their Tmax and measured mean vitrinite reflectance values. The hopane 22S/(22S + 22R), moretane/hopane ratio and sterane parameters are also in good agreement with these thermal maturity assessments. The predominance of odd carbons over even carbons (most common) and/or even carbons over odd carbon numbered n-alkanes, moderate Pr/Ph ratio, low to high Tm/Ts ratio, comparative abundance of sterane C29 (i.e., C29 >C27>C28), Pr/nC17 — Ph/nC18 values, C/S ratio and dominance of vitrinite macerals group with the presence of liptinite macerals demonstrate that the organic matter has derived mainly from terrestrial inputs with an insignificant contribution from the marine sources. The condition of deposition alternates from oxic to anoxic. 相似文献
14.
Solid state nuclear magnetic resonance techniques were used to measure the fraction of aliphatic carbon in oil shales from United States deposits, ranging in age from Ordovician to Tertiary. The aliphatic carbon fraction was shown to correlate with the fraction of organic matter converted to oil during Fischer assay. The fraction of organic matter convertible to oil is a primary factor in evaluating the oil potential of an oil shale resource. Nuclear magnetic resonance determines this in a nondestructive, easily interpreted bulk analysis of the whole rock. 相似文献
15.
民和盆地中侏罗统煤-油页岩层系生油特征 总被引：4，自引：0，他引：4
本文简要论述了民和盆地中侏罗统含煤及油页岩层系的生油特征，探讨了盆地独特的石油地质和地球化学条件。原油主要地化特征为:Ｐｒ/Ｐｈ比值偏高（２.６５-３.１５）、甾烷/藿烷比值极低（０.０３）、Ｃ２７甾烷较丰富、Ｔｓ/Ｔｍ＞１低硫芴/氧芴比值、较高含量的Ｃ２９降新藿烷及重排藿烷类化合物及相对丰富的长链联苯及烷基四氢萘系列化合物。中侏罗统煤－泥页岩层系含生油潜力明显不同的多类型油页岩，多数油页岩属由藻类和陆生高等植物母质组成的混合型有机质，沉积环境为淡水－微咸水弱氧化条件，其地化特征也表现为高Ｐｒ/Ｐｈ比值（平均为１。９８），低甾烷/藿烷及低硫芴/氧芴比值等特征。某些油页岩富含Ｃ２９降新藿烷及重排藿烷系列化合物，它们应为主力源岩。油页岩多含再沉积型或沉积改造型有机质。异常地热作用对源岩演化及原油地化特征有重要影响。 相似文献
16.
以大量烃源岩样品地球化学分析为基础,综合应用钻井以及地震等地质资料,从有机质丰度、类型、成熟度、母质来源、沉积环境以及生物标志物等方面对乌石凹陷流沙港组烃源岩地球化学特征进行了研究。研究结果表明,流三段发育于还原湖泊环境,有机质丰度较高,类型主要为Ⅱ1-Ⅱ2型;流二段沉积于弱还原至还原环境,有机质丰度最高,尤其是流二段油页岩基本为优质烃源岩,有机质类型以Ⅱ1-Ⅱ2型为主;流一段沉积于偏氧化性湖泊环境,有机质丰度最低,类型以Ⅱ2-Ⅲ型为主。依据烃源岩综合演化剖面,将其热演化过程划分为未成熟、低成熟、成熟和高成熟4个阶段,确定了烃源岩生烃门限深度为2900m,生烃高峰位于3600m。低伽马蜡烷指数显示流沙港组沉积时期水体为淡水环境,丰富的4-甲基甾烷表明水生低等植物对烃源岩母质来源有较大贡献。 相似文献
17.
Francis P. Miknis Arthur W. Lindner A. John Gannon Mark F. Davis Gary E. Maciel 《Organic Geochemistry》1984,7(3-4)
Solid state 13C NMR techniques of cross polarization with magic-angle spinning, and interrupted decoupling have been employed to examine the nature of the organic matter in eight kerogen concentrates representing five Tertiary deposits in Queensland, Australia. The NMR results show that five of the kerogens have high proportions of aliphatic carbon in their organic matter and correspond to Type I–II algal kerogens. Three of the kerogens, derived from carbonaceous shales, have a high proportion of aromatic carbon in their organic matter and correspond to Type III kerogens. The fractions of aliphatic carbon in all the kerogens, regardless of type, are shown to correlate with the conversion characteristics of the corresponding raw shales during Fischer assay. Interrupted decoupling NMR results show the presence of more oxygen-substituted carbon in the carbonaceous shales, which may account for the greater CO2 evolution and phenolic materials found in the pyrolysis products of the carbonaceous shales. 相似文献
18.
Organic matter maturity and oil/gas prospects in Middle-Upper Proterozoic and Lower Paleozoic carbonate rocks in northern China 总被引：3，自引：0，他引：3
Middle-Upper Proterozoic and Lower Paleozoic carbonate formations in northern China are well developed with an accumulative
thickness of 6000–1400 m. Both seepages and oils have been found in the outcrops and drilling wells.
The maturity of organic matter in these carbonate formations in obviously lower than that in southern China, as viewed from
reflectance (R°), H/C (atomic ratio), the amount and distribution of hydrocarbons,T
max°C and so on.T
max°C may be used as a principal index for determining the maturity of organic matter in carbonate rock-covered areas. According
to the results of themeasurement ofT
max°C andR° for natural samples and simulating experiments on bitumens from carbonate rocks, the limitation values for oil and gas have
been estimated at 455°C (R°=1.35) and 476°C(R°=2.25), respectively. On this basis, the map of organic matter maturity for the Middle-Upper Proterozoic, Ordovician, Cambrian
and Carboniferous of northern China has been compiled. It has been proposed that prospects of both oil and gas are expected,
with oil and condensate dominant in the Ordovician, and condensate and dry gas in the Middle-Upper Proterozoic. The Cambrian
is intermediate between them. 相似文献
19.
20.
The Thermal Alteration Index (TAI) obtained from spore colouration is a useful maturity indicator that may be obtained from palynological preparations. Thermal maturity is an important parameter in determining the hydrocarbon potential of the Lower Carboniferous lacustrine and fluviatile sediments of the Horton Group, and coeval rocks, of Nova Scotia. Samples studied from fifty-two separate localities indicate a wide range in thermal maturity from low (TAI 2 to 3) to high (TAI 4 to 5?). Variation in depth of burial was probably the main factor responsible for the regional differences in thermal maturity. The thickness of Horton sedimentation varied considerably in a series of half grabens, as did the overburden of post-Tournaisian Lower Carboniferous, Upper Carboniferous, Permian and possibly Triassic rocks.The organic matter in most samples is composed of exinous (Type II) and woody and coaly material (Types III and IV). Locally in a few localities amorphous algal material (Type I) consisting of Botryococcus sp. is common. The composition of the organic matter and the thermal maturity data suggest that in most of the study area rocks of the Horton Group are in the dry gas generation zone, although in some areas oil generation may have taken place; in a few localities where the thermal maturity is high the organic matter has been altered beyond the dry gas preservation limit. 相似文献