Tong X.,China National Petroleum Corporation |
Guo J.,Zhenhua Oil Co. |
Wang Z.,China National Petroleum Corporation
Earth Science Frontiers | Year: 2014
Current development of oil and gas extends from conventional to unconventional that is more difficult and more expensive. In the near future, a situation will be achieved that both conventional and unconventional oil and gas will develop simultaneously. According to the cause of formation, unconventional oil and gas may be divided into three categories. The first category is the heavy oil and oil sands, which are the normal crude oil damaged by biodegradation and water washing; heavy oil and oil sands are widely distributed and highly potential; there is a lot of exploitation of them. The second category is the tight oil and gas, shale oil and gas, and coalbed methane; the main feature is the reservoir porosity and permeability in very poor conditions; they are continuous-massive accumulation reservoir; this category develops very rapid and the production grows very fast. The third category is the oil shale, which is immature kerogen mixed with clay and fine-grained inorganic minerals. Oil shale is rich in organic matter, and can generate oil by heating. Oil shale was found early and widely distributed; the highest proportion of them is in the United States. The unconventional oil and gas exploration and development led the innovation of petroleum geology theory and technology. Meanwhile, unconventional resources are very huge, equivalent to 2-3 times of the conventional oil and gas resources; the exploration and development technologies are maturing, which greatly extends the life cycle of the oil industry, leading the petroleum industry to a great-leap-forward development.
Wang Y.,China University of Petroleum - Beijing |
Yao Y.,China University of Petroleum - Beijing |
Jiang M.,ZhenHua Oil Co. |
Ji Z.,China University of Petroleum - Beijing
Advanced Materials Research | Year: 2012
The evaluation model for horizontal well development has significant value in recoverable reserves uncertainty studies. This paper established an evaluation model on the degree of reserve recovery at different level of water cut, and made a chart of the dimensionless aspect seepage ratio against the degree of reserve recovery in different water cut. Secondly, heterogeneity correction factor and saturation correction factor were introduced to the model of oil recovery. Application of 6 typical horizontal wells in Dagang Oil Company proved that the result of this model satisfied with the actual data, and the model can provide criteria for horizontal well development in a bottom water reservoir. © (2012) Trans Tech Publications, Switzerland.
Wang W.,Zhenhua Oil Co. |
Wang W.,China National Petroleum Corporation |
Tong X.,China National Petroleum Corporation |
Yu L.,Sinopec |
And 2 more authors.
Xinan Shiyou Daxue Xuebao/Journal of Southwest Petroleum University | Year: 2013
Based on the analysis of tectonic evolution and petroleum geology, the author summarized the oil and gas distribution features of northwest shelf of Australia, and discuss the main controlling factors of hydrocarbon accumulation. The results show that the hydrocarbon distribution of northwest shelf of Australia are divisional in plane, oil mainly occurs in NW trend narrow rifts formed during the late Jurassic, while gas mainly distributed in the outer highs adjacent to those rifts. Vertically, hydrocarbon principally occurs in Mesozoic series with a stratified feature, and gas is concentrated in Triassic and Jurassic reservoirs while oil mainly occurred in Cretaceous and upper formations. Hydrocarbon accumulation of northwest shelf of Australia is principally controlled by source rock, structural background, big delta sedimentary systems, regional seal and later preservation conditions. Source rock property and distribution led to the appearance of"rich in gas and poor in oil" of northwest shelf Australia and controlled the oil and gas distribution. Big delta sedimentary systems and fine regional seals provided excellent source-reservoir-seal assemblages, and determined the concentration layers of hydrocarbon. Besides, uplifts and highs adjacent to sags are always the favorable areas with all sorts of traps developed.
Yang Y.-X.,China University of Petroleum - Beijing |
Yang Y.-X.,State Key Laboratory of Petroleum Resource and Prospecting |
Jin Z.-K.,China University of Petroleum - Beijing |
Jin Z.-K.,State Key Laboratory of Petroleum Resource and Prospecting |
And 6 more authors.
Journal of Central South University | Year: 2014
Reservoirs can be developed in the sediment gravity flows. However, high quality reservoirs are found widespread in sediment gravity flows of Gangzhong area, Huanghua depression, Bohai Bay Basin, East China. Characteristics and formation of these reservoirs are key problems to be solved. Through comprehensive analysis of thin section petrography, scanning electron microscopy and X-ray diffraction, two distinct rules were obtained. 1) These high quality reservoirs have apparent characteristics: lithology consists mainly of medium-fine grained sands; moderately-well sorted and rounded; intergranular pores dominating >70% of the entire pores, surface per unit pore volume reaches 15%; average porosity is 21% and average permeability is 55×10-3 μm2. 2) Types of sedimentary microfacies and dissolution strongly control on the formation of high quality reservoirs. Main channels and sandy braided bars have the best reservoir properties. Because that sediments are mainly medium-fine grained sands in high-energy environments. The favorable primary porosity and permeability may promote calcite cementation and help to produce more secondary pores. Besides, at the depth of 2500-3200 m, basically matching threshold of oil generation, organic acid expelled when organic matter became mature, and H+ released during clay mineral transformation. These both result in the dissolution of calcite cements and create large volume pores, then physical properties improve correspondingly. Moreover, deep hydrothermal fluid intrusion may also have impacts on the development of secondary pores. © 2014 Central South University Press and Springer-Verlag Berlin Heidelberg.
Sun Y.,Northeast Petroleum University |
Kang L.,Northeast Petroleum University |
Bai H.,Zhenhua Oil Co. |
Fu X.,Northeast Petroleum University |
Hu M.,Northeast Petroleum University
Acta Geologica Sinica | Year: 2012
A study of faults and their control of deep gas accumulations has been made on the basis of dividing fault systems in the Xujiaweizi area. The study indicates two sets of fault systems are developed vertically in the Xujiaweizi area, including a lower fault system and an upper fault system. Formed in the period of the Huoshiling Formation to Yingcheng Formation, the lower fault system consists of five fault systems including Xuxi strike-slip extensional fault system, NE-trending extensional fault system, near-EW-trending regulating fault system, Xuzhong strike-slip fault system and Xudong strike-slip fault system. Formed in the period of Qingshankou Formation to Yaojia Formation, the upper fault system was affected mainly by the boundary conditions of the lower fault system, and thus plenty of multi-directionally distributed dense fault zones were formed in the T2 reflection horizon. The Xuxi fault controlled the formation and distribution of Shahezi coal-measure source rocks, and Xuzhong and Xudong faults controlled the formation and distribution of volcanic reservoirs of Y1 Member and Y3 Member, respectively. In the forming period of the upper fault system, the Xuzhong fault was of successive strong activities and directly connected gas source rock reservoirs and volcanic reservoirs, so it is a strongly-charged direct gas source fault. The volcanic reservoir development zones of good physical properties that may be found near the Xuzhong fault are the favorable target zones for the next exploration of deep gas accumulations in Xujiaweizi area.
Kou X.,ZhenHua Oil Co. |
Well Testing | Year: 2013
At present the Tahe carbonate rocks oil deposit faces the problem of the production of the oil deposit dropped quickly, and the formation pressure maintains low level. It begins from analysis the microscopic holes structure in the seam holes carbonate rocks oil deposit s to study the reason that some wells initial production can be very high, but it declines very quickly. The mechanism is further discussed for injecting water, pressure-rising, and the stuffy well, and recovery in these wells. A new method for the research of the recovery of Tahe carbonate reservoir is supplied, which can direct the design of further development program.
Shang Y.-Q.,Eastern Liaoning University |
Shang Y.-Q.,China University of Petroleum - Beijing |
Wang Z.,China University of Petroleum - Beijing |
Chen D.-Y.,China University of Petroleum - Beijing |
Chen D.-Y.,Zhenhua Oil Co.
Xitong Gongcheng Lilun yu Shijian/System Engineering Theory and Practice | Year: 2012
Oil price forecasting has always been an important and difficult issue. In this paper, Hull-White model was used to predict the volatility of oil prices and we found defects in the practical application, then Hull-White model has been improved by use a binary tree model. Weekly oil prices from January 3, 1986 to February 12, 2010 were used as a reference value to test the application of improved model, the results showed the improved model has a great application value and practical significance in forecasting the fluctuation range of oil price.
Liu X.-H.,China University of Geosciences |
Lin C.-S.,China University of Geosciences |
Liu J.,H+ Technology |
Yang H.,China National Petroleum Corporation |
Liu C.-H.,ZhenHua Oil Co.
Xinan Shiyou Daxue Xuebao/Journal of Southwest Petroleum University | Year: 2011
Based on the data of core and testing oil, we analyze the causes of low-permeability sandstone reservoir with full consideration to the impact of the grain size, sorting, pore-throat radius, complex pore structure, content of debris and hydrophilic of rock on productivity. The simple sand-shale reservoir model has been subdivided into the silt-sand, fine-sand, sand-medium, sand-shale model. The concept of oil production probability is proposed on the basis of the elaborate reservoir interpretation. The oil-water two-phase fluids rate forecast model, interpretation template and criterion are eventually established according to calculating oil and water production on single well by using the corresponding software which is programmed on superposition method. Correct evaluation on reservoir capacity can help to scientifically guide the exploration and development of oil field. So the logging technology becomes the eye of the geologists and reservoir engineers.