The Mesozoic basinfilling records and the basin distribution and evolution in the north and south margins of the eastern North China Craton are compared, and the Mesozoic configurations are constructed in this paper. The above basins are characterized by similar evolutionary processes: Develop  since the Early Jurassic, the basinfilling evolution from a compressional and lithospheric thickening setting in the PreLate Jurassic to a intracontinental tension and lithospheric thinning setting after Late Jurassic, showing a tectonic regime inversion during the Late Jurassic with a time lag in shallow crust to deep lithosphere. However, the basinfilling records mentioned above also show distinct differences between the two basin systems. Firstly, multiplayer basic, mediumbasic and mediumacidic volcanicpyroclastic assemblages were developed in the north YanshanLiaoxi basins from the Early Jurassic to Cretaceous; but limited calcalkaline volcanic series filled the south Hefei Basin during the Late JurassicEarly Cretaceous. Secondly, the Late Mesozoic lithospheric thinning began at ca. 163 Ma and 149 Ma in the north and south margins, which finally resulted in ca. 145 Ma and 132 Ma structural extensional events in a basinscale, respectively. Thirdly, coarse clastic sediments occurred in the north and south margins during the tectonic inversion phase (Late Jurassic) were  mainly deposited as  fluvial and alluvial facies, respectively indicating topographic difference in elevation evident in the south and nonevident in the north. Fourthly, the Mesozoic depocenter migration shows a complicated track in the north margin but an evident trend from south to north in the Hefei Basin. Therefore, it is presented that basinfilling records in the south margins of the eastern North China Craton were dominantly controlled by the uplift and exhumation which resulted from collisional orogenesis and postorogenesis in the Dabieshan area. On the other hand, the north basin evolution shows a control mechanism induced from intensive crustmantle interaction, with a regional basinrange stress transition from pressingthrusting to spreadingstretching across the tectonic inversion phase. In addition, as mentioned above, the tectonic regime inversion of the North China Craton shows an earlier time limit in the YanshanLiaoxi basins than that in the Hefei Basin, which probably indicates that the Late Mesozoic inversion is firstly driven by a deep crustmantle interaction in the northern North China.

The Chemo palaeouplift is located in the interior of the Junggar Basin. It is oriented in SWNE direction which was formed in the Yanshanian Orogeny. Now it is a monocline with a north to south inclination. The Jurassic of the study area experienced a multistage tectonic movements. Many truncations and onlap unconformity surfaces were developed, thus the study area is profitable for exploration of lithologic petroleum accumulations. By analyses on the eroded stratigraphic thickness and according to the seismic profiles characters, the eroded thickness of the Toutunhe, the Xishanyao and the Sangonghe formations of the Jurassic in the Chemo palaeouplift are reconstructed using the direct seismic profile indexing method combined with the thickness viriation ratio method and the neighboring thickness ratio method. The most intensive erosion occurred in the KuitunMosuowan area, and the largest eroded thickness is 260 m, 340 m, and 140 m respectively for the three formations. The eroded thickness of the Xishanyao Formation in the high palaeouplift was probably formed by twostage tectonic movements, while the eroded thickness of the Sangonghe Formation in the higher palaeouplift was probably from the tectonic movement in the later period. The relationship between the planar distribution characters of the eroded thickness and the formation and evolution of the palaeouplift indicate the late Early Jurassic is the initial forming period of the Chemo palaeouplift, the sedimentary period of Xishanyao Formation is its developing period, and the Late Jurassic is its extensively developing period. The transportation of a great deal of eroded sediment provided the conditions for the lithologic trap formation on the slope area of the palaeouplift. The southern slope area of the Chemo palaeouplift is the profitable petroleum accumulation area.

Based on the macrofeatures and microfeatures of the outcrop sections and the drilling cores of the Leikoupo Formation of Middle Triassic in the northwest Sichuan Basin, and combined with the conventional petrophysical properties, this paper profoundly studies the basic features of the reservoir space types, petrographic and petrophysical properties, vertical distribution, as well as the main  factors controlling sedimentation and diagenesis. Furthermore, it discusses the development and evolution of main reservoirs and predicts the favorable reservoir distribution area. The reservoir concentrates in the middle part of member 3 of the Leikoupo Formation, where the rock types are mainly the sandsized intraclastic dolostone, algaebounding dolostone and macrocrystalline dolostone. The corrosion pore is predominant, while the dissolved cavity and primary pores are subordinate. The fractures play a role in  connecting the pores. The reservoirs are of the pore type of moderate porosity and moderatelower permeability, and the fracturepore type of moderate porosity and high permeability. Study shows that the reservoir is a karst reservoir in which pores are dominated by intergranular dissolved pores, algaebounding  framework dissolved pores and intercrystalline dissolved pores. The original rocks laid down as the intraclast bank and algaebounding  grain bank have experienced  karsting during the  hypergenic and burial stages. The reservoir resulted from the interactive influence of sedimentation and diagenesis. The favorable reservoir is distributed in the ZhongbaShuangyushi block, which is the superimposed area of the bank and karst development zone.

The Songliao Basin is located in the Northeast China, where Daqing and Jilin oilfields were developed. At the period of the Member 4 of Quantou Formation of Lower Cretaceous in the southern Central Depression of the Songliao Basian, the basement subsided uniformly and slowly, and the topography of the basin was very flat, leading to the development of a delta at the setting of shallow water and a rapid rise in lake level. Base on studies of core, main facies markers and welllog facies,the reservoirs are mainly composed of lithic arkoses and feldspar litharenites. Three subfacies and nine microfacies were identified. The subfacies are delta plain, delta front and prodelta. The microfacies are distributary channels, levees, crevasse splays, interdistributary bays, subaqueous distributary channels, subaqueous crevasse splays, mouth bars, distal bars and subaqueous interdistributary bays. Delta plain and delta front were well developed, and prodelta was less developed. The distributary channel advanced toward the center of the lake over a long distance through filling deposition and branching channel frequently, and developed an obvious subaqueous distributary channel at the wide shallowwater delta front. The most oilrich reservoirs are compased of  channel sand bodies which had cut and oversfacked each other. The average width of single sand body is 200 to 600 meters and its thickness is 3 to 8 meters. This study is an important foundation for further oilfield production adjustment and development.

Seismoturbidite is a common kind of petroliferous reservoir in the continental rift lacustrine basin. According to the flume experiment, the forming process of seismoturbidite is simulated. The results show that there are two kinds of slumping in delta front under seism and three kinds of seismoturbidites: liquefied turbidites, secondary slumping turbidites and secondary overlapped turbidites can be formed. They are widely developed in delta front, and they usually overlap vertically and occur in belts regionally. The secondary slumping turbidites are mainly developed in the deep sag below the bed form break and can form one of the most favorable subtle petroleum reservoirs in the rift lacustrine basin. The factors controlling the distribution of seismoturbidites mainly include the sedimentary characteristics of delta front, the intensity of seism and the depositional bed form of delta front.

Principles and methods of sequence stratigraphy for outcrops, drilling cores and well logs have been used for reconstructing the Paleogene sequence stratigraphic framework in the Tarim Basin. Extensive investigations of the outcrop, borehole and well log data revealed that a total of 6 third order sequence boundaries and 5 thirdorder sequences were developed in the Paleogene in the Tarim Basin. Three sequences, namely S1, S2 and S3, were developed from Paleocene to Early Eocene (the deposition period of Kumugeliemu Group and its equivalents). On the whole, S1 is equivalent to the basal conglomerate member, gypsum and gypseous mudstone member to dolostone member of the Kumugeliemu Group in the Kuqa Depression, and is equivalent to the Tuyiluoke Formation in the southwestern Tarim area. S2 and S3 correspond to the two gypsumcontaining members developed in the upper part of the Kumugeliemu Group in the Kuqa Depression, respectively. They are equivalent to the two gypsum intervals in the Aertashi Formationthe Qimugen Formation and the Kalataer Formationthe Wulagen Formation in the southwestern Tarim Depression. Two sequences, S4 and S5 were developed from Late Eocene to Oligocene (the deposition period of the Suweiyi Formation and its equivalents). S4 is equivalent to the Suweiyi Formation in the Kuqa Depression and the main part of the the Bashibulake Formation in the southwestern Tarim Depression, and S5 is only locally developed at the top of the Suweiyi Formation in a few boreholes and it is characterized by the fan delta sandy conglomerates. Within these sequences, the lowstand systems tracts are represented by the conglomerates and sandstones of fan delta distributary channel and braided channel as well as the thickbedded gypsum and gypseous rocks of saline lagoon and evaporate platform. The transgressive systems tracts are dominated by coastalshallow lacustrine mudstones and siltstones, and the highstand systems tracts are mainly composed of the carbonate rocks and mudstoneabundant successions.

The Karakum Basin is the third gasrichest basin in the world next to the Western Siberian and Persian Gulf Basins. Based on the newest reserve data for individual fields, this paper discusses the distribution characteristics and the accumulation model for oil and gas in the basin with an integrated analysis of petroleum geology. Stratigraphic distribution of oil and gas is controlled by regional cap rocks. Oil and gas are concentrated in two reservoir intervals: The Middle Jurassic Callovianthe Upper Jurassic Oxfordian carbonate rocks and the Hauterivian Shatlyk Formation sandstones of Lower Cretaceous. The former hosts 68.0%, 84.0% and 44.2% of the total proved oil, the condensate and the gas reserves in the basin respectively. The latter reservoirs 36.4% of the total gas reserves. High quality reservoirs and paleohigh structures are the main controls on the regional distribution of the oil and gas fields in the subsalt sequences underlying the Upper Jurassic evaporites. The North Amu Darya SubBasin where the reef reservoirs and paleohigh structures were well developed, contains bulk of the subsalt proved oil and gas reserves. The evaporite cap rock and deepcutting large scale fault zone are the main controls on the regional distribution of the oil and gas fields in the suprasalt sequences. These fields are largely confined to the areas outside the evaporite cap rock, the areas with a thin anhydritedominated evaporite sequence and the area near the large fault zone. The suprasalt sequences are not nonexploration intervals for oil and gas, particularly the latter. Gas derived from the subsalt source rocks can migrate upwards to form giant gas fields in the suprasalt reservoirs.

Through systematic sampling and analyses of the lacustrine carbonate rocks in the Cenozoic continental strata in the northern QinghaiTibetan Plateau, by using the carbon and oxygen isotopes as proxies, the environmental evolution of the Early Cenozoic is revealed according to the palaeolacustrine evolu￣tion. The results indicate that the δ¹⁸O and δ¹³C in the bioclastic limestone samples have the lowest values in all the samples in this area, reflecting that they were deposited in an open freshwater lacustrine environment with a short period of water residence. There is a positive relation between the δ¹⁸O and δ¹³C in the micritic limestone samples, reflecting that they were deposited in an obvious closed saline water laustrine environment. The obviously enriching of δ¹³C in stromatolitic limestones may be related to the microbial activities. The δ¹⁸O value of the lacustrine carbonate rocks gradually increased from Eocene to Oligocene and then to Miocene. The δ¹³C changed from a negative value in the Paleogene to a positive value in the Neogene, which reflects that the lacustrine system in this area evolved from an open system to a closed one. Thus the prediction can be made that the palaeoclimate changed greatly throughout the PaleogeneNeogene period.

The oilfield brines with a great quantity of reserves exist in the PaleogeneNeogene in some anticlines of the western Qaidam Basin. They are expected to be the resources to sustain  the Quaternary salt lake brines. By the analyses of the oilfield brines samples collected from the  boreholes in the typical tectonic areas including Xiaoliangshan, Youquanzi, Kaitemilike, Youdunzi, and Youshashan and the saline lake brine samples, and intercrystal brine samples on earth, the hydrochemistry characteristics and resource distribution are discussed. Compared with the evaporate curves of the marine water and the Qinghai Lake water, the chemical evolution of the oilfield brines is analyzed. The results indicate that the resources of K, B,Li are much higher than the industrial grade. Br and Sr also reach the industrial grade. Thus the exploration and utilization prospect of oilfield brines is very good. The planar distribution of oilfield brines is characterized by most enriching in the central Nanyishan anticline and reducing toward the north and the south. Vertically, the oilfield brines are more likely to enrich in the deep interval than in the shallow interval intercrystal brines and the lacustrine water. The chemical evolution of oilfield brines is dominated by waterrock reaction, mixing, evaporation and condensation of deep water and salt rock dissolution. These processes provide good geochemical conditions for the brines evolution and accumulation. 

Based on the analyses of lithology, grain size and sporopollen of sediments from the DGY borehole in the Taihu dishlike depression, this paper discusses the evolutions of vegetation, climate and geomorphology in the Taihu dishlike depression since 8ka BP.The records of sporopollen show that the arbor vegetation changed from deciduous broadleaf trees and conifer trees to deciduous and evergreen broadleaf trees  during 8～5 kaBP. This indicates that the palaeoclimate changed from warm dry to hotwet during this period of time. The shrinkage of forests reflects a cool and dry climate during 5～4 ka BP. A cooling event occurred at ～4ka BP. During 4～3ka BP, the forest was mainly composed of evergreen broadleaf trees, reflecting a warm and wet climate. Since 3 ka BP, the forest was mainly composed of conifer trees and evergreen and deciduous broadleaf trees, reflecting a warmmoist climate. Interpretations of sporopollen records also suggest a cooling trend with some fluctuations during this period. The records of sporopollen, lithology and grain size show jointly that muddy silt of lagoon facies prevailed in the area during 8～5 ka BP, reflecting an open depositional environment effected by seawater. Freshwater marsh prevailed  and the seawater effect vanished during 5～4 ka BP, reflecting the shrinkage and  isolation of the lake area. The lake area growths and saltwater intrusion occurred during 4～3 ka BP, suggesting the formation of the dishlike depression of the Taihu drainage area.Freshwater marsh which was influenced occasionally by tidewater has prevailed since 3 ka BP, reflecting the further development of the dishlike depression in the study area.

The Daaosha is located in the nearmouth section of the Xijiang estuarine of the Pearl River Delta. The boundary of tidal influence during flood season is near the top of the Daaosha. Two boreholes (PRD04 and PRD05) were drilled in the proximal and central parts of the Daaosha respectively. The core records show that the sedimentation rates and sediment grain size are quite different between PRD04 and PRD05 since the postglacial period. PRD04 exhibits lower sedimentation rates than PRD05 prior to 7630 aBP, but hihger since 7630 a BP. The sediments in PRD04 are poorlysorted, and the sediment grain size is coarser when the burial depth is below 12.28 m, but the sediments become finer and wellsorted above 12.28 m compared with PRD05. Analyses indicate that the sediments were transported by flood currents from south to north during 9000~4200 a BP. The flood currents eroded the previously deposited sediments. With a marked decrease in current velocity after the flood currents passed through the Modaomen channel, the coarsegrained muds and sands accumulated first, while the finegrained sediments were transported further towards the north. Since 3500a BP, the sediments in the north became coarser than those in the south, suggesting that the sediments were transported from the north to the south due to the change to river dominance. The formation of the Daaosha was closely related to the flood jet. The flood jet inlet, with a width about 2 200 m, was situated between the Shedi Hill and the hills along the right bank of the Xijiang River.