In the first comprehensive study of the Termit Basin petroleum system, an integrated organic geochemistry and basin modeling study of potential source rocks and related oils was conducted to evaluate source rock potential, classify oil families, establish oil -source correlation, and explain the distribution of petroleum systems. Six hundred forty-three cutting samples from the Paleogene Sokor1 Formation, Upper Cretaceous Yogou and Donga Formations, and Lower Cretaceous K1 Formation were analyzed using total organic carbon, Rock-Eval pyrolysis, vitrinite re flectance, and kerogen element analysis. The results suggest that the Sokor1, Yogou, and Donga Formations are poor to excellent source rocks with type I, II, II -III, and III kerogen, and most of the samples are thermally mature and within the oil window. Samples from the K1 Formation have poor organic richness and are thermally mature to postmature. In vertical, samples from the upper member of the Yogou Formation have greater organic matter richness and contain more oil-prone type I and oil-prone type II organic matter than those from the lower member. In horizontal, samples from the Donga Formation on the east side of the basin are dominated by very oil-prone type I and oil-prone type II organic matter and have higher hydrocarbon generation potential than those on the west side, which mainly contain oil- and gas-prone type II -III and gas-prone type III organic matter. One-dimensional basin modeling results demonstrate that the Sokor1 source rocks are mature in the northwestern part of the basin, are immature on the eastern side at present-day, and oil generation began in the early Oligocene. The Yogou source rocks are in the early oil to wet gas stage at present-day, and oil generation began at the end of the Late Cretaceous. The Donga source rocks are in the late oil to dry gas stage at present-day, and oil generation commenced in the middle Late Cretaceous. The maturation of these source rocks increased rapidly during the Oligocene due to active rifting. Three families (I, II, and III) were identi fied by hierarchical cluster analysis, principal component analysis, and stable carbon isotope compositions for 97 oil samples and eight rock extracts. Most of the oils (family I) were derived from Yogou source rocks, and their extensive distribution and wide range of thermal maturities are closely related to the large area of mature Yogou source rocks in the basin. Family II oils occur in the northwestern part of the basin and are genetically related to Sokor1 source rocks. The family III oil occurs on the east side of the basin and originated from the Donga Formation. This study con firms the existence of three petroleum systems between the Paleogene and Upper Cretaceous and helps to identify exploration prospects and guide petroleum resource assessment in the Termit Basin.

Based on seismic and drilling data, core samples, geophysical attributes and previous researches (including fossils and geochemical analysis results published), this paper analyzes the depositional system of Termit Mesozoic and Cenozoic rift basin by focusing on source-sink study, and discusses its controlling effects on hydrocarbon accumulation. (1) This paper established late Cretaceous Yogou "fluctuated falling sea level source-sink depositional model" and Paleogene Sokor 1 "fluctuated rising lacustrine level source-sink depositional model" of Termit basin. Marine and continental facies, post-rift and rift, regression and transgression, "lower larger scale post-rift sediment range" and "upper smaller scale rift sediment range", which all indicate the specialty and hydrocarbon significances of the basin. (2) During the late stage of Late Cretaceous, meandering river delta prograded basinward, gradually turning from marine facies to transitional facies, thus inverse cycle was developed. A large amount of continental organic matters were transported to the slope and center area of the basin during the late Yogou Formation and formed the main source rock of the basin. The delta front sandstone developed in this period interbedded with source rock, where hydrocarbon could accumulate in; Major provenance areas locate in the eastern and southern part of the basin, and the lithologic traps developed in these slope area had good exploration potential; (3) during the early stage of Paleogene rift period, the faults were reactivated. The basin gradually evolved from Madama fluvial facies to lacustrine environment. Braided river delta retrograded, and normal cycle was developed, which was different from that of Late Cretaceous. During the rift climax and the maximum flood period, thick layers of mudstone were deposited. They became regional cap rocks of the basin, and formed the main reservoir and cap rock assemblage with the underlying delta sandstone of Sokor 1 formation. Combined with activated faults connecting the late Cretaceous source rocks, they jointly formed the dominant play of this area. The main provenances locate in the western and eastern part of the basin during this period, and large quantity of hydrocarbon could accumulate in both sides.

The study area K is located in the center of the Fana Low Uplift in the Termit Basin, Niger, which is known as one of hydrocarbon-prone zones in this basin, where the oil producing Paleogene Sokor reservoir is dominated by the delta front underwater distributary channels and estuary bars, and the facies variation is fast, leaving the prediction of the distribution of favorable sand bodies the key issue for the further oil-fields development. In this article, the regional sedimentary characteristics, drilling and seismic data are integrated to study the sedimentary characteristics. It is believed that the Paleogene Sokor1 Formation mainly developed underwater distributary channel, estuarine bar, distal bar, interdistributary bay, beach bar sand and shore-shallow lake mud sedimentary microfacies. Through intensive well seismic calibration and forward modeling, the logging curves and seismic reflection characteristics of different lithologic associations are identified, and it is believed that seismic reflection characteristics have good correlation with sedimentary microfacies, and the well-seismic characteristics and seis-mic facies identification chart of 6 sedimentary microfacies in the study area are generated. On this basis, the spatial distribution of underwater distributary channel sand bodies are accurately characterized by using Frequency-Decomposed Multi-Seismic-Attributes RGB Fusion, seismic attribute analysis and other research, incorporated with drilling calibration and forward modeling. The result is consistent with the plane calibration of the drilled well, which provides a geological basis for the planning of development wells.

东尼日尔盆地群属于西非裂谷系.基于地震、钻井、井壁取心和地球化学分析数据等资料，针对下组合新层系Donga组，从沉积体系分析入手，探讨其成藏组合和勘探潜力.Donga组为晚白垩世海侵背景下发育的一套正旋回沉积层序，下粗-中上部细，顶部发育薄层碳酸盐岩.该层序在东尼日尔盆地群跨多个盆地广泛发育和连续沉积，预示着晚白垩世盆地群形成了暂时统一盆地.海侵事件显著影响了晚白垩世的沉积体系，控制了其含油气系统发育和油气成藏.Donga组广泛沉积的泥岩为有效烃源岩和盖层.Donga组主要发育侧向对接供烃“上生下储”和“自生自储”成藏模式.储层是Donga组成藏主控因素，盆地群埋藏适中、近物源的北部和东南部边缘相带储层发育，具备较好勘探潜力.

西非裂谷系由一系列中—新生代裂谷盆地组成,Grein坳陷位于西非裂谷系北部,对其开展构造特征及形成演化过程研究对认识西非裂谷系形成演化具有重要意义.本文基于最新二维地震数据,对Grein坳陷开展构造几何学特征解析,在此基础上运用构造平衡恢复方法进行了构造运动学恢复,结合区域大地构造背景,对Grein坳陷的成因机制进行探讨.研究结果表明:(1)Grein坳陷整体呈缓坡断阶型半地堑结构,具有明显的"东断西超"特征.坳陷南北差异较大,北部呈断阶形态,南部为凹陷形态;(2)Grein坳陷白垩纪—第四纪构造演化包括两期裂谷作用,可划分为5个阶段,即早白垩世断陷沉积期(Ⅰ),晚白垩世稳定沉积期(Ⅱ),白垩纪末构造反转期(Ⅲ),古近纪断陷沉积期(Ⅳ)和新近纪—第四纪稳定沉积期(Ⅴ);(3)Grein坳陷白垩纪末构造反转期主要受非洲—阿拉伯板块与欧亚板块碰撞影响,板块碰撞使非洲板块内部发生了两次强烈构造事件,分别为晚白垩世圣通期(Santonian)和马斯特里赫特期(Maastrichtian),其中马斯特里赫特期(Maastrichtian)构造活动在Grein坳陷内部表现明显,该时期坳陷发生构造反转,西北部被抬升,使得上白垩统地层发生剥蚀.

Based on the seismic and drilling data, casting thin sections, geochemical analysis of oil and rock samples, and hydrocarbon generation history simulation, the hydrocarbon accumulation characteristics and exploration direction of Termit superimposed marine—continental rift basin are discussed. The Termit basin is superimposed with two-phase rifts (Early Cretaceous and Paleogene). The subsidence curves from two wells on the Trakes slope in the east of the basin show high subsidence rate in the Late Cretaceous, which is believed to be high deposition rate influenced by transgression. However, a weak rift may also be developed. The depositional sequences in the Termit basin were controlled by the Late Cretaceous marine transgression cycle and the Paleogene lacustrine transgression cycle, giving rise to two types of superimposed marine—continental “source-sink” deposits. The marine and continental mixed source rocks developed universally in the whole basinduring the marine transgression period, and are overlaid by the Paleogene Sokor 1 reservoir rocks and Sokor 2 caprocks developed during the lacustrine transgression period, forming the unique superimposed marine—continental basin in WCARS. The early low geothermal gradient in the Termit basin resulted in the late hydrocarbon generated by the source rock of Upper Cretaceous Yogou in Paleogene. Mature source rock of Upper Cretaceous Donga developed in the Trakes slope, so that the double-source-supply hydrocarbon and accumulation models are proposed for the Trakes slope in which formed the oil fields. Due to virtue of the newly proposed hydrocarbon accumulation model and the exploration activities in recent years in the Termit superimposed marine—continental rift basin, an additional effective exploration area of about 2500 km2 has been confirmed in the east of the basin. It is believed that potential domains such as Sokor 1, Donga and Upper Cretaceous lithologic traps in the southeast of the basin are key expected targets for exploration and frontier evaluation in future.

Based on seismic and drilling data in the study area, the geological structure and kinematic process of the Termit rift basin were studied using seismic profile interpretation and balanced restoration to find out the dynamic mechanism of the basin. (1) The geological structure of the Termit Basin is represented as a narrow rift basin, with development of series of structural styles in extensional, extensional strike-slip and compressional stress setting. On plane, it is narrow in the north and wide in the south, and transitions from graben to half-graben from north to south; it features a graben controlled by the boundary faults in the north and a fault-overlapped half-graben in the south. (2) Before the Cretaceous, a series of hidden faults developed in the West African rift system, which laid the foundation for the development location and distribution direction of the Termit Basin; during the Cretaceous to Paleogene periods, the basin experienced two phases of rifting in Early Cretaceous and Paleogene, which controlled the initial structure and current structural shape of the basin respectively; during the Neogene to Quaternary, the basin was subjected to weak transformation. (3) In the Precambrian, the Pan-African movement gave rise to a narrow and long weak zone within the African plate, which provided the pre-existing structural conditions for the formation of the Termit Basin. In the Early Cretaceous, affected by the South Atlantic rifting, the Pan African weak zone was reactivated, resulting in the first stage of rifting and the basic structural framework of the Termit Basin. In the Paleogene, affected by the subduction and convergence of the Neo-Tethys Ocean, the African-Arabian plate extended in near E-W trending, and the Termit Basin experienced the second stage of rifting. The oblique extension in this period caused intense structural differentiation, and the current structural pattern of alternate uplifts and depressions took shape gradually.

尼日尔Termit盆地目前已发现90％的储量位于古近系Sokor1组,但是对其主力产层的砂岩储层质量的影响因素仍然缺乏深入研究.本文基于55口井的71 m岩心和568个井壁取心样品资料,开展普通薄片、铸体薄片、X衍射及扫描电镜分析,研究Sokor1组E5-E1各段的储层特征,并探讨其影响因素.研究表明,E5-E1段储层的岩石类型主要为石英砂岩与岩屑石英砂岩,成分成熟度高;结构成熟度低-中等,以细粒和不等粒结构为主,分选中等-差;磨圆差,一般为次棱角-次圆状.孔隙类型以原生孔隙为主,其次为粒间溶蚀孔;成岩作用弱-中等,主要处于中成岩A期阶段.E5-E1段储层孔渗正相关性好,其中E5和E2段储层质量最好,以中孔-中渗和高孔-高渗为主,E4、E3和E1段储层质量次之且非均质强.通过分析,揭示了沉积微相是影响储层质量的主要因素,成岩作用次之.分流河道和河口坝是优质储层发育的主要环境,砂岩中粘土杂基含量是影响储层非均质性的主要因素.

KN area is located in the East of KN depression in Muglad Basin. It has lower exploratory level, only two-dimensional survey lines are distributed in most areas before, and the quality of seismic data is poor. Three wells have been drilled in this area, only one well has low oil production in Bentiu formation, and the other two wells have failed. However, oil was discovered in multiple targets in H area, which is in the SouthEast of KN area. In order to evaluate the oil and gas potential of KN area, combined with the new seismic data of KN 3D area, it is carried out of comprehensive geological and geophysical research work in KN area. By means of well correlation, precise seismic interpretation, tectonic evolution analysis and drilled wells analysis, and comparing with the reservoir forming conditions of adjacent H area, it is concluded that the oil source fault and forming time of traps are the important factors to form the oil and gas reservoir. On this basis, the residual potential of KN area is reevaluated, and it is concluded that the Eastern fault step zone is a favorable area for further exploration.

Esso等多家国际油公司在尼日尔Termit盆地勘探36年,未获商业开发储量规模而退出.中国石油通过技术评价和商务一体化结合,于2003年进入Termit盆地,制定"分步走"勘探策略,一方面在盆地已有发现的西部进行滚动勘探落实储量,另一方面通过攻关核心地质问题,明确主力含油气层系和勘探方向.研究认为:(1)Termit盆地为发育两期裂谷和两期坳陷的叠合裂谷盆地,且在晚白垩世遭受海侵,与中西非地区其他陆相裂谷盆地有所差异;(2)古近系下部砂泥岩互层与上部区域性泥岩构成主力储盖组合;(3)建立了海陆叠合裂谷油气成藏模式,指导发现了4个亿吨级油田群,勘探获得巨大成功,成为海外自主勘探的又一典型成功案例.形成3个启示:(1)技术评价和商务一体化运作是尼日尔区块获取的重要原因;(2)陆相裂谷石油地质理论和技术的成功应用是Termit盆地勘探成功的前提;(3)建立Termit盆地成藏模式是勘探获得重大突破的主因.

CNPC achieved its scaled hydrocarbon discoveries in the Paleogene Sokor1 Formation in Termit basin, Niger in the recent years. Despite the substantial potential is revealed by the latest exploration activities in the Paleogene Sokor2 Formation, studies and literatures on hydrocarbon accumulation of the Sokor2 Formation are rarely reported. In this study, based on the sequence correlation of wells, sedimentology analysis and seismic data interpretation, the Sokor2 Formation is subdivided into three sand units, i.e. the S21, S22 and S23 sand units. The formation slicing and multi-attribute combined impedance inversion technology are used to carry out reservoir prediction. The characteristics of the sedimentary system of the Sokor2 Formation in the Paleogene are well defined. The sedimentary system of the shoreline shallow lake dominates the development of the underwater distributary channels, estuary dams, and far sand dams in the delta front around the lake. It is pointed out that the S23 sand group can be an effective reservoir. It can be a new exploration play in the Termit basin. During the study, it was further raised that the southern Dinga Terrace, southern Yogou Terrace and southern Moul Trough are favorable zones for the new exploration play of S23 sand unit, which guided the recent exploration activities with new successes. The new understanding raises the “regional cap rocks” as a new hydrocarbon exploration play, which filled the research gap of the region. Through this study, the new hydrocarbon exploration play of Sokor2 Formation is defined to widen the exploration domain, which will support the sustainable hydrocarbon discovery in the Termit basin.

Almost 90% of reserves was discovered in the Paleogene Sokorl Formation in Termit Basin, Niger. However, impacts on reservoir quality of these sandstones are still poorly studied. Petrographic of these sandstones of 71m conventional cores and 568 sidewall core samples from 55 wells was studied with thin sections, casting thin sections, X-ray diffraction and SEM investigations. Based on the results, the authors analyzed the lithological characteristics of the Sokorl sandstones (ES, E4, E3, E2 and El members) and explore the related factors. The results show that the rock types are quartz sandstones and lithic quartz sandstones which are characterized by high component maturity, low-medium texture maturity and poor-fair rounding. Fine grained and inequigranular textures are dominated types with poor-medium sorting and subangular-subrounded grains. Poor-medium diagenesis and middle diagenetic A stage of E5-E1 sandstones lead to well-developed primitive intergranular and intergranular dissolution pores. Porosity and permeability data based on cores show a good positive relationship in E5-E1 sandstones. E5 and E2 reservoirs are of the highest qualities, and they are characterized by medium porosity and medium permeability, and some with high porosity and high permeability. However, the reservoir quality of E4, E3 and El sandstones are characterized by strong heterogeneity. Microfacies of sandstones is the key controlling factor for the reservoir quality, while diagenesis is the second controlling factor. Distributary channel and mouth bar are the best sedimentary environments for high quality reservoirs in the study area. Clay matrix content in the sandstones plays an important role for reservoir heterogeneity.

Systematic geochemical analysis of 39 crude oils from the Termit Basin, Niger, all belonging to the same oil family, reveals distinct differences in bulk properties and molecular compositions, which were undoubtedly caused by differences in the extent of biodegradation. Various degrees of microbial alteration were identified in crude oils, which were classified as non-, slightly, moderately, or heavily degraded oils, according to their physical properties, bulk chemical compositions, and certain molecular biomarker characteristics. Examination of the possible origins and geological backgrounds of the biodegraded oils shows that reservoirs with deeper burial depths (greater than 1800 m), thicker caprocks (>100 m), relatively higher stratigraphic temperatures (>80 degrees C), and which have been subject to the influence of silent faults had not suffered significant biodegradation. The burial depth of reservoirs is therefore considered to be the main factor controlling the biodegradation process, and may offset other factors if the depth is sufficient. The Paleogene reservoirs in the Dinga Step-Fault Zone (DSFZ) that meet all of these conditions are therefore dominated by normal oils. Degraded oils of varying degrees are widely distributed in other tectonic units where at least one of these factors is absent. This study may have practical application for further petroleum exploration, prediction of petroleum properties, and the reduction of production risk.

A suite of 23 crude oil samples from the Termit Basin, Niger, were analyzed for geochemical characterization of thermal maturity and family classification. Distribution of alkylnaphthalenes, alkyl phenanthrenes, triaromatic steroids and aromatic biomarkers were reported from aromatic fractions of these oils. Oil-oil correlation suggests that these oils in Termit basin show two typical different geochemical characteristics, and can be divided into two different groups, and most of the oils belongs to family I. Methyl triaromatic steroids, and relatively higher abundance of triaromatic dinosteroids in these oils from Family I indicate a characteristics of crude oils of marine origin. Methyl triaromatic steroids and triaromatic dinosteroids were detected in the oils from Family II, and triaromatic dinosteroids are present in lower abundance relatively to methyl triaromatic steroids. The maturity values calculated by the methyl phenanthrene index (MPI-1) and trimethyl naphthalene ratio 2 (TNR-2) suggest that these oils most probably were generated by source rocks with the maturation stage of 0.6% to 1.0% (Ro). The oils from the Family II appear to have relatively higher maturity. This is the first study to report the distribution of aromatic hydrocarbons from the Termit Basin crude oils. The identification of family II in this basin can further improve the hydrocarbon play concept as well as provide new insights of hydrocarbon exploration with the Basin.

Sixty-five genera and 115 species of dinoflagellate cysts were discovered in the samples from the depth of 600-2652 m in the Facai-1 Well in the Tenere Graben of Niger, Africa. The low diversity and abundance in each single sample make it difficult to divide the dinoflagellate cyst assemblage into biozones. The dinoflagellate cyst assemblage is indicative of a Late Cretaceous age and suggests an abnormal neritic palaeoenvironment.

中西非裂谷系位于非洲中部,主要为沿中非剪切断裂带分布的被动裂谷盆地,进一步划分为中非裂谷系和西非裂谷系.针对国内外对勘探程度极低的中西非裂谷盆地白垩系优质烃源岩展布、发育机理及油气成藏模式认识薄弱的现状,笔者在开展大量中西非裂谷盆地上、下白垩统两类烃源岩样品的主微量元素等地球化学分析的基础上,从含油气盆地构造、烃源岩发育古环境、古气候、古生产力和有机质保存条件等分析出发,剖析了不同类型含油气盆地优质烃源岩发育主控因素,分别建立了中、西非裂谷系低勘探程度含油气盆地下白垩统、上白垩统优质烃源岩的发育模式:中非裂谷盆地(Bongor、Muglad、Melut盆地)下白垩统裂陷期快速沉降、温暖湿润气候条件下,勃发的水生有机质(藻类)控制的深水湖相优质烃源岩"生产力"单因素发育模式;西非裂谷盆地(Termit盆地)上白垩统拗陷期海侵、炎热潮湿气候条件下,陆源有机质输入为主,优越的保存条件(偏咸水体)优质海相烃源岩"生产力+保存条件"双因素控制的发育模式.从而进一步锁定富油气凹陷和主力成藏组合,有效指导含油气盆地内选区选带,助推油气规模储量发现.

分析和研究肉羊产业生产与发展,对山丹县肉羊产业持续健康发展和增加农牧民收入有着重要意义.本文对山丹县肉羊产业生产基本情况做了介绍,对肉羊产业发展中存在的问题进行了分析,提出了一些建议.

成岩作用在沉积岩形成演化过程中占有重要位置.由于不同盆地沉积及构造演化的差异性,导致其成岩作用也有不同的特点.以样品实验分析为基础,开展尼日尔Termit盆地白垩系砂岩成岩作用研究,明确了该盆地白垩系砂岩成岩作用的主要类型及其对储层的影响;根据成岩现象、黏土矿物特征与变化规律、包裹体均一温度等多个方面对该盆地白垩系砂岩储层进行成岩阶段划分,认为研究区白垩系砂岩大多处于中成岩A阶段,埋藏较浅的砂岩处于早成岩B阶段.Termit盆地白垩系砂岩的岩石类型是影响成岩作用的一个重要因素,由于该盆地白垩系砂岩以石英砂岩为主,石英颗粒的强支撑作用减弱了压实作用对储层的破坏,原生粒间孔是最为发育的孔隙类型,此外还发育少量粒内孔隙、粒间溶孔等孔隙.Termit盆地不同区带白垩系砂岩储层的发育具有一定的差异,Fana低凸起和Yogou斜坡储层相对较发育,储层物性好;Soudana隆起带和Dinga断阶储层物性差.Fana低凸起具有很好的勘探潜力,从钻探结果中也得到了证实,是后续白垩系勘探的重点区带.

The Paleogene lacustrine mudstone is one of the most important sets of source rocks in Termit Basin, Niger. However, studies on the Paleogene source kitchen are scarce. In this study, the source rock types, spatial distribution and their hydrocarbon generative potential within the Paleogene Sokor-1 and LV formations are systematically evaluated. A total of two third-order sequences (SSQ1 and SSQ2, from the bottom to top) and six systems tracts were identified in the Sokor-1 Formation, while the LV Formation mainly comprises pure shale and is regarded as a compositive stratigraphic sequence with no need of subdivision. Six types of source rocks could be distinguished within the three depositional environments of the sequence stratigraphic framework: (1) deep lake mudstones and shale deposited in the lacustrine deep-water facies, (2) shallow lake mudstones and carbonaceous mudstones occurring in the shallow lake environment, and (3) deltaic-front mudstones and prodeltaic mudstones developed in the deltaic facies. Deep lake mudstones/shale, which mainly occurred in the SSQ1-TST (transgressive systems tract), SSQ2-TST and LV Formation, are considered organic-rich source rocks with oil-prone generative potential. The shallow lake mudstones and deltaic mudstones were predominantly distributed in the tectonic slope and marginal areas of the Agadem Block within the lowstand systems tract and high stand systems tract of the SSQ1 and SSQ2. Nevertheless, geochemical results indicated that the deltaic mudstones are good gas-prone source rocks but the shallow lake mudstones were classified as poor potential source rocks. The variance in organic matter accumulation and preservation conditions within different depositional facies and the fluctuation of relative lake level are the controlling factors for the occurrence and distribution of high-quality source rocks. The effective Paleogene source kitchen is limitedly distributed around the depocenter of the Dinga Depression within a small scale, and therefore exploration for oil and gas resources from the Paleogene source kitchen should focus on the eastern Dinga fault-step zone adjacent to the depocenter of the Dinga Depression.

Petrography of the Upper Cretaceous sandstones of 218 side-wall coring samples from 17 wells was described by thin section, cathodoluminescence, X-ray diffraction techniques and heavy mineral analysis. Based on the result, we try to study the lithological characteristics of the Upper Cretaceous sandstones and explore the related factors. The results show that the Upper Cretaceous sandstones, having high component maturity, are quartzarenite with quartz percentage more than 86%. There is little content of potash feldspar, calcite and plagioclase in the rock with the content of about 5%. This kind of rock is more advantageous to the preservation of primary porosity. Pore-filling cements mainly consist of clay minerals with the content of about 7%, which are dominated by kaolinite. It is favourable to the preservation of intergranular pore. The cements are mainly siliceous, calcite and ferruginous. Because the Content of cement is little, the damage to the reservoir is not effective. Main heavy minerals include magnetite, hematite, zircon, apatite, indicating that the Upper Cretaceous sandstones may be source from granite rocks. With low texture maturity, mainly have fine grained texture and minor inequigranular texture. Grains are mainly characterized by point contact and subangular-subcircular rounding, with fair to poor sorting. It is different from domestic quartz sandstone that deposited in coastal environment; the quartz sandstone in the study area has high component maturity and low structural maturity. It Indicate that the source rocks may be rich in quartz, and the same time the sandstone deposited in the near source fluvial deltas. Cementation is the main factor that influences the Upper Cretaceous sandstones. Because main sandstones are quartzarenite, compaction has less negative effect on reservoirs which helps to maintain porosity of sandstones. The face rate is more than 15% if the buried depth of sandstone is less than 2500 meters. Dissolution, common in feldspar dissolution, has certain influence on the Upper Cretaceous reservoir. Dissolution produces intergranular and intragranular dissolved pores, and enlarges primary pores, which improves reservoir performance.