Based on outcrops, rock cores, seismic, well logging, and other data, the study traces the evolutions of sequence stratigraphy, the types of sedimentary facies and sequence development control factors of Es3 in the Kenxi slope zone of Bohai Bay basin. The findings show that the stratum in this area can be divided into three third-order sequences, eleven fourth-order sequences and seven system tracts; the types of sedimentary facies include fan delta, sublacustrine fan, semi-deep lake, and deep lakes, etc.; sedimentary facies belt, lithologic trap patterns, hydrocarbon migration and preservation conditions are the core factors controlling lithologic reservoirs in this area. The exploration prospect in this area have been predicted. It is believed that there is a large exploration potential in the upper Es3 sub-member, the south of well K25-1 of the west Kenxi prominence.

With the fast development of the offshore oilfield in china, field engineers are now facing with a new challenge, which is the flow assurance of crude oil-water two phases flow in the submarine pipeline. Since the existence of natural surfactants in the crude oil, as resin, asphaltene and etc, crude oil and water two phases tend to form stable water-in-oil (w/o) emulsion and therefore greatly influence their flowing characteristics, as flow patterns and transition characters and especially the pressure drop character. These have shown obvious differences from the flow of mineral oil-water two phases, which are commonly and widely used for indoor experiments, even when the density and viscosity properties of the mineral oil and crude oil phase are approximately the same. For the guidance of the design and operation of the offshore crude oil-water pipeline, high viscosity mineral oil / crude oil-water two phase flow through horizontal pipe were conducted in a steel laboratory pipe loop (1 inch inner diameter, 52m length). Major similarities and differences are compared between their flow patterns and transition characters. Copyright 2010, Society of Petroleum Engineers.

The effect of cooling rate on the structure of Na2Si3O7 glass was studied by Raman spectroscopy. The shape of Raman spectra of glasses varies with cooling rate. By fitting the high-frequency region of the Raman spectra with Gaussian curves, the abundance of SiO4 tetrahedra with different number of non-bridging oxygens (Qn) are deduced. The structural species Q4 and Q2 increase with cooling rate and Q3 decrease with cooling rate. Providing the faster cooling rate leads higher temperature feature of melt to preserve in glass, the changes of structural species in Na2Si3O7 glass with cooling rate are consistent with the in situ high-temperature Raman results. From this study the rate-dependent glass structure should be taken into consideration in the glass processing, even with ordinary cooling technique.

From high-temperature molten, a series of silicate melts near cotectic-line were quenched or cooled with different rate. The experiment samples are analyzed by micro-Raman spectroscopy. The changes of melt structure of Abx Anx Diy silicate melts across phase border are compared systematically. The heredity of crystal structure from melt structure is also discussed. It is shown that the relative concentration of melt structure unit varies abruptly in some extent across the phase border. The changes of melt structure have different effects on melt viscosity and density. The Raman spectroscopy measurements indicate that silicate glass structure is insensitive to cooling rate. From the point of heredity of crystal from melt, it means that the crystal growth units are closely related with melt structure units.

The Jiyuan Depression is a frontier area for oil and gas exploration in Henan Province, China. In recent years, oil was discovered in the Deng-2 well in the lower Tertiary, though the tectonics and petroleum geology of the Depression are very complex. A series of experiments on fluid inclusions in the oil-bearing sandstones from the Deng-2 well were made that included measurement of the homogenization temperatures of gas–liquid inclusions and GC–MS analysis of biomarkers either in the sandstone pores or in the fluid inclusions. The Deng-2 oil-reservoir was formed at about 78°C, corresponding to a burial depth of about 2200m. The present burial depth is about 700m because of erosion and fault-block uplift in Oligocene time. Although oil in the sandstone pores is now heavily biodegraded, the biomarkers in the inclusions show slight biodegradation representing a watering and biodegradation process that did not occur before formation of the Deng-2 oil-pool. Having investigated the structural evolution of the Deng-2 trap, it is concluded that the oil discovered in the Tertiary reservoir of Deng-2 well migrated from Mesozoic reservoirs through active faults around the Deng-2 trap. As the oil migrated from the Mesozoic to the Tertiary reservoir, the Deng-2 trap was uplifted close to the depth of active biodegradation (subsurface temperature lower than 80°C and to a burial depth shallower than 2250m from the thermal gradient of 3.1°C/100m) so that the oil in the inclusions shows a slight biodegradation. Because of the continuous uplift of the Deng-2 trap during the Tertiary and Quaternary, the reservoired oil has been more heavily biodegraded compared to that in the inclusions.

The single crystal form of the petal and the total morphology of the chrysanthemum stone have been measured. The petal crystallographic direction has been decided and some parameters of the total morphology have been found. Based on above mentional a growth mechanism is suggested in this paper with which explained the formation of the characteristics of the morphology of the chrysanthemum stone.

Abstract: There are a group of large and medium‐scale Meso‐Cenozoic petroliferous basins along both sides of the Tanlu fault or within the fault zone, e.g., the Songliao basin, the Bohai Bay basin and the Subei‐Yellow Sea basin. As shown by studies of the structural types, sedimentary formations, volcanic activities, tectonic evolution as well as the time‐space relationship between the Tanlu fault zone and the basins, the formation and distribution of the basins are controlled by the movement of the Tanlu fault. This paper presents an analysis of the tectono‐geometric, kinematic and geodynamic features of the basins on the basis of integrated geological‐geophysical data, and an exploration into the internal relations between the fault and the basins as well as the formation mechanism and geodynamic processes of the basins.

Large quantities of immature and low‐maturity oil have been discovered in the North Jiangsu Basin, East China. Intense tectonic activity and the differential accumulation of immature oils during the Palaeogene have resulted in reservoir rocks which have variable sedimentary and diagenetic characteristics. Studies of oil geochemistry and reservoir diagenesis suggest that oil generation and accumulation took place early in the basin's history (i.e. during early diagenesis), significantly inhibiting later modification of the reservoir rocks. There has been no large‐scale tectonic activity since the oil pools formed, and the reservoirs' petrophysical properties and pore construction therefore reflect early diagenesis. Diagenetic modification of the reservoir rocks was more intense below the oil‐water interface where oil did not accumulate. Alteration in these rocks included calcite cementation, the formation of quartz overgrowths, and the development of pressure solution.

Jinhu sag is located in the west of Dongtai depression of Subei basin. Member II of Funing formation is one of the major reservoirs in Xiyuan area of Jinhu sag. The reservoir consists of limestones and sandstones. Reservoir microheterogenity was characterized by analysis on the content of the rocks, petrophysical property, diagenesis, pore structure and potential sensitivity of clay minerals. The result supplies a reference for development of Xiyuan oilfield.

Diagenesis and pore-constructure of biograin limestones or sandstones keep close relationship with the oil accumulation in the Xiyuan-Cuizhuang area of Jinhu depression. The oil-bearing reservoirs with high storage capacity had some large porethroat and good connection in the pores. The limestones and sandstones without oil were obviously strong in calcite cementation and grain growing, so they had poor storage property and pore-constructures, and even lost storage capacity. The oil generation and accumulation in the area showed that the discovered oil was immature one generated and accumulated in early time. The accumulated oil restrained further cementing and grain growing in the reservoirs occupied earlier by the immature oil. The reservoirs kept the petrophysical and pore-constructure features of those at the start of the B-subperiod of early diagenetic stage. Storage capacity of reservoirs was controlled by their diagenetic evolution, and the diagenesis is controlled by early hydrocarbon migration and accumulation as well as differential activity of fault traps.