辽河盆地东部凹陷深部煤层气成藏条件评价

辽河盆地是我国煤、油、气共生盆地之一，开展该盆地东部凹陷深部煤层气成藏条件评价，对于优选煤层气有利探区，实现该区煤层气与常规油气共采具有重要意义。从气源条件、储集条件和保存条件3个方面，分析了东部凹陷深部煤层气的成藏条件，并对其进行综合评价，结果表明东部凹陷具有煤层分布面积广、厚度大、变质程度低、含气量低、含气饱和度高、埋藏较深、煤层气地质储量丰富及保存条件良好等特点，认为该区煤层气成藏条件较好，能够实现与常规油气共采，具有很好的勘探开发前景。     

辽河盆地东部凹陷煤层气勘探选区模糊综合评价

辽河盆地是我国煤、油、气共生盆地之一, 东部凹陷煤层具有发育面积广、厚度大、变质程度较低、埋藏较深等特点。开展东部凹陷煤层气选区评价, 对于优选煤层气有利勘探区, 实现该区非常规煤层气与常规石油天然气共采具有重要意义。选取煤层累计厚度、含气量、含气饱和度、煤层气储量丰度、煤层连续性和盖层条件作为评价因素, 建立 了适合研究区的模糊综合评价模型, 并在此基础上, 应用模糊综合评判方法对东部凹陷煤层气选区进行综合评价。结果表明, 热河台-三界泡区和欧利坨子区为有利区, 其中, 热河台-三界泡区煤层具有厚度大、连续性好、埋深较浅等有利因素, 是东部凹陷煤层气最有利勘探区。     

海拉尔盆地煤层气成藏机理及勘探方向

海拉尔盆地是中生代白垩系含煤盆地，煤层气总资源量约2×10¹²m³。为确定该盆地煤层气勘探潜力，通过研究该区煤层厚度、埋深、煤岩煤质特征及演化程度、煤储层物性及含气性、煤层气保存条件和资源分布等因素，弄清了该盆地煤层气的分布特征。结果认为，海拉尔盆地具有很好的煤层气富集成藏条件，其中尤以盆地东部呼和湖凹陷的煤层气成藏地质条件为最好。该凹陷具有煤层厚度大、分布面积广、储层孔隙发育、顶底板封盖性能好的特点，煤层气资源量达1.25×10¹²m³，占全盆地煤层气总资源量的62％，是今后首选的煤层气勘探目标。     

二连盆地霍林河地区低煤阶煤层气成藏条件及主控因素

我国越来越重视对低煤阶煤层气的勘探,但已有的资料表明,目前对低煤阶煤层气藏的认识还不够深入。为此,以我国典型的低煤阶煤层气区——二连盆地霍林河地区为例,对该区煤层气地质特征和煤岩煤质及煤岩演化程度、煤储层渗透性、煤层含气性等煤储层特征进行了分析,从构造条件、封盖条件及水文地质条件3个方面研究了煤层气藏主控因素及保存条件。结论认为:霍林河地区煤层气成藏条件有利,具有煤层厚度大、煤层埋深较浅、煤储层渗透性好、含气量较高、封闭保存条件好等特点;保存条件是该区煤层气成藏的主控因素,且封闭条件好的浅部是煤层气富集的有利区。     

低煤阶煤层气成藏机制与勘探突破——以吐哈—三塘湖盆地为例

吐哈—三塘湖盆地煤层气资源丰富,但低煤阶煤层气成藏机制认识不足制约了该区煤层气的勘探开发。为此,在系统分析煤系地层地质特征的基础上,从沉积环境、构造特征、封盖条件和水文地质条件等方面分析和总结了煤层气富集主控因素和成藏模式,并明确了该区煤系气的有利勘探区带。研究结果表明：(1)古地貌和古环境控制煤岩的发育程度,稳定的正向构造是煤层气富集指向区,顶底板稳定的泥岩封盖条件是煤层气富集的必要条件,地表水补给是晚期生物气生成和富集的关键;(2)该区煤层气成藏可划分为缓坡区多气源补给煤层气富集、山前带复杂断块浅层煤层生物气、深层砂煤共储煤系气富集以及南部残余凹陷深部洼槽区煤层气富集4种模式;(3)条湖凹陷—马朗凹陷北部斜坡带、台北凹陷北部山前带西段浅层是煤层气最有利目标区,淖毛湖凹陷东部、沙尔湖凹陷东洼槽是煤层气较有利目标区,台北凹陷核桃沟—柯柯亚、鄯勒、照壁山—红旗坎、鄯善—温吉桑、疙瘩台构造带以及条湖凹陷中部构造带是煤系气富集有利区。结论认为,低煤阶厚煤层煤层气可以获得高产工业气流,吐哈—三塘湖盆地深部煤层气资源具有良好的勘探开发前景。     

惠民凹陷深部煤层含气性预测

在我国煤、油、气共生盆地中,常规石油天然气与非常规煤层气能否实现共采是近期关注的热点问题。基于济阳坳陷惠民凹陷外围不同煤级煤样吸附性的物理模拟,结合石油天然气探井实测的温度和压力资料,对该区深部(2 000 m以深)煤层的含气性进行了预测,结果表明该区深部气煤―肥煤的原位含气量在5.0 m3/t左右。     

中国低煤阶煤层气多元成藏特征及勘探方向

我国低煤阶含煤盆地地质背景复杂,煤层气富集成藏具有自身的特殊性,煤层气勘探一直处于小型试验阶段。为了促进我国低煤阶煤层气的勘探开发,在系统分析、总结我国含煤盆地类型、煤层气成因、赋存状态、富集模式的基础上,梳理了目前勘探开发工作面临的挑战与科研攻关目标,并提出低煤阶煤层气的有利勘探方向。结果表明:(1)我国低煤阶煤层气具有盆地类型多元、煤层气成因类型多元、赋存状态多元、富集类型多元的成藏特征;(2)低煤阶煤层气勘探面临目标区优选、深层煤系气共探共采系统评价、钻完井及增产改造工艺等3个方面的挑战;(3)应加强对煤层气成藏过程及动力学机制、气源成因及其资源贡献、吸附态和游离态煤层气空间分布规律及地质控制因素等的研究攻关,开展煤层气资源有效性和可采性评价,形成一套深部煤系气勘探开发评价方法。结论认为:(1)我国浅层煤层气资源有利勘探区包括二连盆地吉尔嘎朗图、霍林河、白彦花等凹陷,海拉尔盆地伊敏、呼和湖、陈旗等凹陷,鄂尔多斯盆地彬县、焦坪、黄陵、乌审旗东部等地区,以及准噶尔盆地南缘地区;(2)深层煤层气资源则主要分布在准噶尔、吐哈、三塘湖、海拉尔和三江等盆地或盆地群。     

二连盆地吉尔嘎朗图凹陷低煤阶煤层气富集模式

二连盆地为我国典型低煤阶褐煤分布区,煤层气资源丰富,但煤层气富集成藏机制认识不足制约了该区低煤阶煤层气的勘探开发。为此以二连盆地吉尔嘎朗图凹陷低煤阶煤层气为研究对象,从煤层分布、含气性、煤层气成因、生物成因气模拟实验、保存条件等方面研究了该区煤层气富集的主控因素,并指出了下一步的勘探方向。研究结果表明:(1)浅水湖盆聚煤环境下,凹陷中部—缓坡带厚煤层发育,厚煤层弥补了含气量的不足;(2)含煤段堆积过程中,浅水湖泊周期性出现使得煤层上覆泥岩周期性发育,盖层条件有利;(3)凹陷中部—缓坡带位于地下水承压区,水动力侧向封堵有利于煤层气富集;(4)研究区煤层气为生物成因,原位条件下煤样产气0.25 m L/g,现今仍有生物气生成。结论认为:(1)厚煤层发育区、具备生物气生成以及良好的封盖条件并处于水动力承压区为吉尔嘎朗图凹陷煤层气富集成藏的关键;(2)吉尔嘎朗图凹陷煤层气富集模式为生物气+承压水封堵煤层气富集,中部—缓坡带L12—S88井区为下一步煤层气建产的有利区。     

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近年来低煤阶煤层气在美国粉河、尤因它盆地进行大规模商业性开采，引起包括中国在内的许多国家关注。中石油煤层气勘探项目经理部对我国西北、东北、内蒙古、滇黔桂地区中、新生代低煤阶含煤盆地煤层气成藏条件及资源分布进行了研究，发现我国低煤阶煤层气资源非常丰富，是我国煤层气勘探不可忽视的重要资源。2003年优选吐哈盆地沙尔湖凹陷进行了积极探索，取得了很好的效果，初步分析了低煤阶煤层气成藏控制因素，指出低煤阶煤层气藏一般埋藏浅，含气量低，但煤层渗透性好。勘探目标选择应注意对煤层气保存条件的分析，寻找高饱和含气区。另外，低煤阶煤层气开发还需要煤层有一定的厚度，这样才能保证较高的资源丰度、单井产量，达到长期稳产的目的。     

马达班湾盆地东部上新统岩性气藏控制因素

马达班湾盆地东部上新统砂体比较发育,且紧邻生气凹陷,具有油气成藏的优越条件。文章对马达班湾盆地东部上新统岩性气藏的油气成藏条件进行了综合分析,建立了研究区斜坡带与凹陷带岩性气藏的成藏模式。研究认为,研究区新构造运动为该区岩性气藏的形成提供了良好的地质背景,优越的区域位置和良好的烃源岩为该区岩性气藏的形成与富集奠定了基础,沉积体系的时空分布控制了岩性圈闭的发育与分布,具有良好的储盖组合与保存条件,骨架砂体与断层等为油气提供了良好的运移通道。结合国内外岩性气藏的研究现状,该区岩性气藏可划分为砂岩上倾尖灭气藏、断层-岩性气藏2种,且以断层-岩性气藏为主。研究区斜坡带下部与凹陷带的成藏条件优越,为岩性气藏的有利发育带。     

PETROLEUM PROSPECTS OF CRETACEOUS SEDIMENTS OF THE CAMBAY BASIN, GUJARAT, INDIA

The Cambay Basin in the NW part of the Indian Peninsula is a commercial petroleum producer from Tertiary sediments resting on the basic lava flows known as Deccan Traps. Cretaceous sediments which underlie the Deccan Traps are exposed in the eastern and western margins of the basin and are also encountered in the subsurface. The paleogeographic reconstruction of the Cambay Basin suggests that the northern part, possessing a thin cover of Cretaceous sediments, has meagre petroleum prospects. However, the southern part of the basin, where more than 1,000 m of Cretaceous sediments were deposited by two independent drainage systems, may be more lucrative. Suitable facies for generation and accumulation of petroleum are expected in this part of the basin.     

RELATIONSHIP BETWEEN AGES OF SHIELDS, DIPS OF ADJACENT SEDIMENTARY BASEMENTS, AND OCCURRENCE OF OIL AND GAS

Crystalline shields can become stable at different times. This stability is commonly marked by the end of magmatism and compressive deformation and the beginning of deposition of platformal sedimentary sequences. The margins of the shields are then the basements for undeformed sediments that dip away from the exposed crystalline rocks. Dips of basements on shield margins directly underlying Phanerozoic sediments have been determined in seven areas in which the margin has not been altered by rifting or other tectonic activity. The adjacent shields have stabilization ages ranging from more than 3,000 m.y. to 600 m.y. The basement dips (tilts) increase progressively from about 3 m/km for older shields to 16 m/km adjacent to the youngest shield (the Nubian-Arabian shield). These tilts can only approximately be recalculated into uplift rates of the shields or subsidence rates of their margins. The dips are, however, consistent with Phanerozoic uplift rates of Archean cratons of less than 5 m/m.y., or comparable subsidence rates of the margins; such low uplift rates could be caused almost wholly by erosion and isostatic adjustment. Younger shields have undergone some other, as yet unidentified, process that causes more rapid uplift. The higher dips of basements around younger shields apparently promote the development of thick sections of mildly-deformed Phanerozoic sediments. Sequences of this type are commonly favorable for accumulation of commercial concentrations of oil and gas. A correlation has been found between age of shield, basement dip, and hydrocarbon occurrence around the western edge of the Canadian shield and the northern edge of Africa. The data show that oil and gas are more abundant in Phanerozoic sediments adjacent to younger shields, which supports the common observation that the world's largest hydrocarbon accumulation (the Arabian Gulf) is adjacent to the world's youngest shield (the Nubian-Arabian shield). This criterion for hydrocarbon accumulation may be of some value in exploration of little-known areas. For example, basements of different ages occur adjacent to the overthrust belt of the northern Rockies, and the generally-young age of Precambrian basement in the eastern US may indicate considerable thickness of sediment under crystalline thrusts in the Appalachians. Different ages of shields in different parts of China may also have broadly affected sedimentary patterns in that country.     

PETROLOGY, PROVENANCE, AND DEPOSITIONAL ENVIRONMENTS OF THE RESERVOIR SANDSTONES OF OSSU-IZOMBE OILFIELD, IMO STATE, NIGERIA

Upper Eocene immature subarkoses derived from Cretaceous sedimentary rocks, older granites and metamorphic rocks, form the reservoir sandstones of the Ossu-Izombe oilfield, Imo State, Nigeria. These sandstones accumulated as part of a deltaic deposit. The vertical section of deltaic facies consists, from base to top, of a progradational sequence (prodelta and delta front), an aggradational unit (delta plain, marsh and interdistributary bay), and an overlying transgressive shallow marine interval. This sequence was penetrated by nearly all of the 15 wells drilled in the area. Reservoir sandstones are present within the distributary mouth bars, point bars, braided stream deposits, and the shallow marine interval.
Thin section studies, electric-log analyses, and data from modern deltas have aided in establishing the environments of deposition of these sandstone bodies. The principal results of this study are: (1) the basal C sandstone represents distributary mouth bar sands deposited at water depths of about 10 m; (2) the intermediate B group consist of point bar and distributary channel sandstone deposits of the lower delta plain; (3) the A-2 sandstone tops the deltaic cycle as a product of braided streams; and (4) a shallow marine deposit, the A-1.1 and A-1 sandstones, occurs at the top of the deltaic cycle.     

HEAVY METALS AND PETROLEUM HYDROCARBONS CONTAMINATION OF BOTTOM SEDIMENTS OF EL SUKHNA AREA, GULF OF SUEZ, EGYPT

The concentrations of total petroleum hydrocarbons (TPH), total organic carbon (%TOC) and petroleum related heavy metals beside the grain size distribution of El Sukhna area, Egypt were determined in the bottom sediment. Copper, zinc and nickel concentrations were found within the lowest effect, while lead and cadmium levels were close to and high to the lowest effect, respectively. The contaminations level were found due to petrogenic origin and their sources are either weathered or highly weathered crude oils and or used lubricating oil. Their detection gives an indication of recent and continuous petroleum inputs.     

MCM-48介孔分子筛热、水热及酸碱稳定性研究

系统考察了MCM-48介孔分子筛在接近实际应用条件下的热、水热及酸碱稳定性.结果表明,该介孔材料在高温及酸性条件下具有较好的稳定性;但在高温水热及碱性条件下,稳定性较差.对于介孔分子筛,其孔道的规整度、骨架Q4的含量及孔壁厚度是决定该材料稳定性的关键因素.     

HEAVY METALS AND PETROLEUM HYDROCARBONS CONTAMINATION OF BOTTOM SEDIMENTS OF EL SUKHNA AREA,GULF OF SUEZ,EGYPT

The concentrations of total petroleum hydrocarbons (TPH), total organic carbon (%TOC) and petroleum related heavy metals beside the grain size distribution of El Sukhna area, Egypt were determined in the bottom sediment. Copper, zinc and nickel concentrations were found within the lowest effect, while lead and cadmium levels were close to and high to the lowest effect, respectively. The contaminations level were found due to petrogenic origin and their sources are either weathered or highly weathered crude oils and or used lubricating oil. Their detection gives an indication of recent and continuous petroleum inputs.     

N,N'-亚甲基双丙烯酰胺的合成研究

以丙烯酰胺和多聚甲醛为原料 ,浓盐酸为催化剂 ,在 1 ,2二氯乙烷溶剂中于 76～ 78℃下反应 2 h,合成了 N,N 亚甲基双丙烯酰胺 ,收率可达 83% ,IR谱图与进口纯样一致。讨论了影响合成的各种因素。     

GEOCHEMICAL CHARACTERIZATION OF A BIODEGRADED CRUDE OIL, ASSRAN FIELD, CENTRAL GULF OF SUEZ

A crude oil sample from the Assran field in the Central Gulf of Suez (Egypt) was analysed geochemically and characterized in terms of a variety of source and maturity dependent biomarkers. Biodegradation was indicated by increasing concentration ratios of Pr/n-C₁₇ and Ph/n-C₁₈. However, biodegradation was only slight as GC-MS analyses of the saturate and aromatic fractions showed that hopanes, steranes, aromatic steroids and polycyclic aromatic compounds including sulphur heterocycles remained intact. The sterane and hopane distributions showed a predominance of C₂₇ steranes, a low diasterane index, an abundance of gammacerane, a high homohopane index and an oleanane index < 0.2. The results indicate that the Assran-10 crude oil was derived from a marine carbonate source deposited in a highly reducing saline environment with a high bacterial contribution, consistent with the Upper Cretaceous Brown Limestone or Lower Eocene Thebes Formation containing Type IIS kerogen. Maturity parameters based on changes in the stereochemistry at chirality centres in hopane and sterane nuclei, such as C₃₀βα/(βα+αβ) and C₃₁ 22S/(22S+22R) hopanes and C₂₉ββ/(ββ+αα) and C₂₉ 20S/(20S+20R) steranes, together with triaromatic sterane cracking ratios, indicate that the oil sample was marginally mature. The results also suggest that biodegradation is probably due to sulphate-reducing anaerobic bacteria.     

利用测井资料解释砂岩储集层孔隙结构的方法

本文提出,先用压汞资料和实验室测定的渗透率资料建立起一组不同压力下的P-Shg-k关系曲线.然后根据测井曲线解释的渗透率值,通过图解或计算,求得各压力点及该点上的饱和度,作该渗透率解释值的毛管压力曲线.这种方法为利用测井资料研究储集层孔隙结构提供了一个可能的途径.实测的和重建的毛管压力曲线,在马岭油田上获得了很好的相似性.     

THE HYDROCARBON EXPLORATION OF THE BASINS OF THE ROSS SEA,ANTARCTICA, FROM MODELLING OF THE GEOPHYSICAL DATA†

Geophysical definition of the three major sedimentary basins of the Ross Sea and scientific drilling on their margins have provided enough information for conceptual models of hydrocarbon generation and source rock character to be applied. The Waples-Lopatin geochemical model used is an accepted part of preliminary exploration in petroleum frontier areas where data are limited. The model has only a narrow empirical base despite widespread use by the exploration industry, but its value is in the collation and utilization of a variety of parameters which control the physical environment of hydrocarbon generation. This modelling evaluation attempts to overcome the condemnation of a region because of the lack of data rather than the lack of true petroleum potential. In the Ross Sea, the Deep Sea Drilling Project (DSDP) holes 270–273 showed that methane and heavier hydrocarbons are present in the drilled sequences. However, to be significant, they must be indicative of regional generation and not just the result of local anomalies. Modelling shows that there are areas of the Ross Sea where the conditions for hydrocarbon generation should be present and these areas are worthy of future exploration.