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Discovery of a Late Permian Angara-Cathaysia mixed flora from Acheng of Heilongjiang,China,with discussions on the closure of the Paleoasian Ocean

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Science China Earth Sciences 2009年第12期52卷 1746-1755页

作者： DENG ShengHui1,2. WAN ChuanBiao3 & YANG JianGuo3 1 Research Institute of Petroleum Exploration and Development, PetroChina, Beijing 100083, China 2.state key laboratory of enhanced oil recovery, Beijing 100083 China 3 Daqing Institute of Petroleum Exploration and Development, PetroChina, Daqing 164712. China Research Institute of Petroleum Exploration and Development PetroChina Beijing China state key {2. of enhanced oil recovery Beijing China Daqing Institute of Petroleum Exploration and Development PetroChina Daqing China

This work documents a new flora from the Upper Permian Hongshan Formation of Acheng County, Heilongjiang Province, Northwest China. The flora consists of 2. species: Paracalamites sp., Pecopteris tangwangheensis Huang, Callipteris obese Huang, Callipteris shenshuensis Huang, C. tangwangheensis Huang, C. heilongjiangensis Huang, C. zeilleri Zalessky, C. sp., Comia yichunensis Huang, C. tenueaxis Huang, Iniopteris sibirica Zalessky, Supaia teiliensis Huang, Compsopteris tchirkovae Zalessky, C. cf. adzvensis Zalessky, Nilssonia sp. 1, Nil. sp. 2. Taeniopteris cf. densissima Halle, T. cf. nystraemii Halle, T. sp. and Noeggerathiopsis derzavinii Neub. It is dominated by Angara species but mixed with some typical Cathaysian elements. The age of the flora is assigned to late of the Late Permian according to the stratigraphic ranges of the known species and the comparisons of it with the similar floras. The new discovery indicates that the final collision between the North China Plate and Siberian Plate occurred in Late Permian along the Xar Moron River-Changchun-Yanji sutured zone, and the Paleoasian Ocean was finally closed at the end of the Permian.

关键词： Late Permian mixed Angara-Cathaysia flora Paleoasian Ocean plate collision Heilongjiang Province of China

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Stability and water control of nitrogen foam in bulk phase and porous media

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Petroleum Science 2009年第2期6卷 181-187页

作者： Zhao Renbao Hou Yongli Ke Wenqi Yue Xiang＇an key laboratory of Petroleum Engineering Ministry of Education China University of Petroleum Beijing 102249 China Research Center of enhanced oil {2. China University of Petroleum Beijing 102249 China

Foam is widely used in the petroleum industry thanks to its unique properties and performance. Its application to water control in oil wells has received more and more attention. The stability of nitrogen foam was investigated in pressurized equipment and sand pack. The result indicated that with increasing pressure （0-2.MPa） the stability of foam in the pressurized equipment increased linearly. Increased nitrogen injection pressure caused better dispersion of nitrogen-foaming solution in porous media. The initial residual resistance factor to gas was an exponential function of injection pressure, but the residual resistance factor （to gas and liquid） decreased exponentially with time. The halflife of foam in porous media （expressed in residual resistance factor） was much longer than that in bulk phase （expressed in foam height）. Pore model analysis indicated that good dispersion in porous media and the presence of thick liquid film during dispersion were the main reasons for high stability. Field test indicated that effective residence of foam in the formation not only resulted in much better heat insulation, but also improved steam stimulation by enhancing steam heating.

关键词： enhanced oil {2. foam porous media permeability residual resistance factor,residence time

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SEEPAGE ABILITY OF HIGH-PRESSURE HOT COMPOSITE FOAM IN POROUS MEDIA

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Journal of Hydrodynamics 2010年第1期22卷 90-95页

作者： WANG Ke-liang LIANGShou-cheng YUAN Xin-qiang CHEN Jin-feng The key laboratory of {2. oil and Gas recovery of the Ministry of Education Daqing Petroleum Institute Daqing 163318 China College of Civil and Environmental Engineering University of Science and Technology Beijing Beijing 100083 China The Second oil Production Company of Daqing oilfield Company Ltd. Daqing 163414 China

The technology of hot composite foam displacement refers to the injection of high-temperature flue gas and foaming and stabilizing agent into wells with a certain concentration, and after meeting the formation water, a composite foam system is formed in the reservoir. This foam displacement technology involves thermal function and so is related to nitrogen, carbon dioxide and foam flooding characteristics. After analyzing seepage flow law of hot composite foam system, seepage flow experiment of composite foam under high pressure was conducted, and seepage flow ability of hot composite foam in porous media was investigated. In the experiment, surfactant HY-3 was chosen as the foaming agent and hot flue gas was chosen as the foaming gas, and high-pressure hot foaming apparatus was employed in experiments. The experimental results indicate that the surfactant HY-3 could form stable foam in porous media, and the foam has strong ability of plugging. It is concluded that the sealing performance of foam is improved with increasing permeability and resistance coefficient and with incresing injection rate and foam strength. After foam injection, sealing characteristics of heterogeneous cores is better than that of homogeneous cores. The foam pressure has a process of transmission in porous media. In this process, with the increase of injection volume, pressure from the inlet to the outlet increases gradually, which indicates that stable foam has been formed inside the core.

关键词： composite foam surfactant HY-3 seepage flow under high pressure porous media

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NUMERICAL SIMULATION STUDY ON SURFACTANT FLOODING FOR LOW PERMEABILITY oilFIELD IN THE CONDITION OF THRESHOLD PRESSURE

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Journal of Hydrodynamics 2008年第4期20卷 492-498页

作者： YIN Dai-yin PU Hui key laboratory of {2. oil recovery of Ministry of Education Daqing Petroleum Institute Daqing 163318 China Department of Chemical and Petroleum Engineering University of Wyoming Laramie WY USA 82070

Based on the non-Darcy flow characteristics of surfactant flooding in the low permeability oilfield, considering the changes of threshold pressure and influence of surfactant on convection, diffusion, adsorption and retention, a mathematical model is established for a three-dimensional, two-phase, three-component surfactant flooding. A new treatment for the changes of threshold pressure and a novel correction method for the relative permeability curve in the process of surfactant flooding are derived, which enhances the matching degree between the mathematical model and field practice. The mathematical model was used to perform the numerical simulation study for a pilot test of surfactant flooding in Chao 45 Block of Daqing oilfield, a proper injection plan was optimized. After the optimized plan was carried out in oilfield, the desirable effects, like pressure-reducing, injection rate increase, and the increase of oil recovery, were achieved. The average oil increase for single well reaches 37%, the ratio of cost to revenue is above 1：4, so the economic effect of scale is promising.

关键词： low permeability surfactant non-Darcy flow threshold pressure gradient numerical simulation

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FINITE VOLUME METHOD FOR SIMULATION OF VISCOELASTIC FLOW THROUGH A EXPANSION CHANNEL

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Journal of Hydrodynamics 2009年第3期21卷 360-365页

作者： FU Chun-quan JIANG Hai-mei YIN Hong-jun SU Yu-chi ZENG Ye-ming key laboratory of {2. oil and Gas recovery of Ministry of Education Daqing Petroleum Institute Daqing 163318 China China National Offshore oil Company Research Center Beijing 100027 China China National Offshore oil Corporation Limited Beijing 100010 China oil recovery Plant No.1 Daqing Oilfield Corp. Ltd. Daqing 163001 China

A finite volume method for the numerical solution of viscoelastic flows is given. The flow of a differential Upper-Convected Maxwell （UCM） fluid through an abrupt expansion has been chosen as a prototype example. The conservation and constitutive equations are solved using the Finite Volume Method （FVM） in a staggered grid with an upwind scheme for the viscoelastic stresses and a hybrid scheme for the velocities. An enhanced-in-speed pressure-correction algorithm is used and a method for handling the source term in the momentum equations is employed. Improved accuracy is achieved by a special discretization of the boundary conditions. Stable solutions are obtained for higher Weissenberg number （We）, further extending the range of simulations with the FVM. Numerical results show the viscoelasticity of polymer solutions is the main factor influencing the sweeo efficiency.

关键词： Upper-Convected Maxwell (UCM) model finite volume method viscoelasticity sweep efficiency

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An experimental study of fracture initiation mechanisms during hydraulic fracturing

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Petroleum Science 2011年第1期8卷 87-92页

作者： Yan Tie Li Wei Bi Xueliang key laboratory of {2. oil ＆ Gas recovery Ministry of EducationNortheast Petroleum UniversityDaqing Heilongjiang163318China

The mechanism of fracture initiation is the basic issue for hydraulic fracture technology. Because of the huge differences in fracture initiation mechanisms for different reservoirs,some successful fracturing techniques applied to porosity reservoirs are ineffectual for fractured *** tests using a process simulation device were performed to confirm the characteristics of fracture initiation and propagation in different *** influences of crustal stress field,confining pressure,and natural fractures on the fracture initiation and propagation are *** results demonstrate that stress concentration around the hole would significantly increase the fracture pressure of the *** the same time,natural fractures in the borehole wall would eliminate the stress concentration,which leads to a decrease in the fracture initiation pressure.

关键词： Hydraulic fracturing porosity reservoir fractured reservoir fracture initiation fracture propagation simulation experiment

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Mechanisms of oil displacement by ASP-foam and its influencing factors

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Petroleum Science 2010年第1期7卷 100-105页

作者： Wu Wenxiang Pan Jianhua Guo Mingri key laboratory of {2. oil and Gas recovery Ministry of Education Daqing Petroleum Institute DaqingHeilongjiang 163318 China

ASP-foam （ASPF） is a system prepared by injecting natural gas into the conventional alkali- surfactant-polymer （ASP） system. Foam can be formed in the porous media by the interaction of gas and surfactant in the ASP system. With the ASPF system, oil recovery is improved as the interfacial tension （IFT） is reduced to a relatively low level, and the swept volume is enlarged. In this paper, four surfactants were evaluated and characterized by IFT between ASP system and oil and the foaming performance. AI- kyl benzene sulfonate （ORS-41） was chosen as the surfactant to best reduce IFT between displacement fluids and oil and improve the foaming performance. The mechanisms of ASPF flooding were studied in this paper, the results show that the ASPF flooding not only enlarges the swept volume but also enhances the displacement efficiency. The effects of reservoir heterogeneity, the gas-liquid ratio of ASPF system, and the concentrations of polymer and surfactant on the displacement efficiency were studied. A field trial of ASPF flooding has also been conducted. Both the laboratory results and the field trial results show that the ASPF flooding can significantly increase the oil recovery, with a 30% increase in the proportion of the original oil in place recovered compared with water flooding.

关键词： oil displacement by ASPF system oil displacement mechanism displacement efficiency influencing factor

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Distribution,formation and evolution of sand ridges on the East China Sea shelf

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Science China(Technological Sciences) 2010年第3期53卷 822-828页

作者： ZHAO RenBao 1,2.SUN HaiTao 3,WU YaSheng 3 &ZHAO ChuanFeng 1,2.1MOE key laboratory of Petroleum Engineering,China University of Petroleum,Beijing 102.49,China 2.{2. oil Recovering Research Center,China University of Petroleum,Beijing 102.49,China 3Faculty of Natural Resource&Information Technology,China University of Petroleum,Beijing 102.49,China MOE key laboratory of Petroleum Engineering China University of Petroleum Beijing China enhanced oil Recovering Research Center China University of Petroleum Beijing China Faculty of Natural Resource & Information Technology China University of Petroleum Beijing China

Influence of CO2.corrosion on reservoir mineralogical composition,pore structure and their mechanical characteristics was studied using XRD,SEM,rock tri-axial machine and core flow experimental *** was found that the corrosion effect was mainly attributed to rock texture and structure,fluid composition and external dynamical conditions in the experimental *** cores with bedding structures,their bedding surfaces were the preferential corrosion regions,because micro-cracks would evolve at these surfaces in the pressure-releasing ***,for cores with massive structures controlled by stable water environment,the CO2.corrosion would result in pore enlargement and secondary pore *** gas velocity from outlet showed sharp increase in the injection process of CO2.H2. *** could be explained by two changes caused by *** was the opening and closure of *** other was particle *** the corrosion time increased,both tensile strength and compressive strength decreased,which confirmed decrease of cementation *** should also be noted that permeability increase and micro-cracks generation would pose damage to the capacity of CO2.geological storage.

关键词： carbon dioxide geological storage mineralization enhanced oil recovery corrosion

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The effects of temperature and acid number of crude oil on the wettability of acid volcanic reservoir rock from the Hailar oilfi eld

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Petroleum Science 2010年第1期7卷 93-99页

作者： Xie Quan He Shunli Pu Wanfeng key laboratory of Petroleum Engineering Ministry of Education China University of Petroleum Beijing 102249 China state key {2. of oil and Gas Reservoir Geology and Exploitation Southwest Petroleum University Chengdu Siehuan 610500 China

Wettability of acid volcanic reservoir rock from the Hailar oilfield, China, was studied with crude oils of different acid numbers generated from an original crude oil with an acid number of 3.05 mg KOH/g. The modifed oils and their resultant acid numbers were： A （2.09 mg KOH/g）, B （0.75 mg KOH/g）, C （0.47 mg KOH/g）, D （0.30 mg KOH/g）, and E （0.18 mg KOH/g）. Contact angles and improved Amott water indexes were measured to study the effects of temperature and acid number on the wettability of the acid volcanic reservoir rock. Experimental results indicated that the wettability was not sensitive to variation in temperature when using the same oil, but the acid number of the crude oil was a key factor in changing the wettability of the rock. The Amott water index, Iw was an exponential function of the acid number, and the Amott water index increased as the acid number decreased （i.e. Amott water index exponentially decreased with the acid number increase）. The Iw value of the core saturated with oil A, with an acid number of 2.09 mg KOH/g, ranged from 0.06 to 0.11, which indicated low water wetness. If the acid number of the oil decreased to 0.18 mg KOH/g, the Iw value increased to 0.95, which indicated strong water wetness. The contact angle decreased from 80~ to 35~ when the aid number decreased from 0.75 to 0.18 mg KOH/g, indicating a change towards more water wet conditions. The oil recovery by spontaneous imbibition of water also increased as the acid number of the oil decreased. As an example, at 80 ~C, the recovery of oil A with an acid number of 2.09 mg KOH/g was only 7.6%, while oil E with an acid number of 0.18 mg KOH/g produced 56.4%, i.e. an increase of 48.8%.

关键词： Acid volcanic reservoir rock Amott wettability index wetting angle temperature acid number wettability

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INVESTIGATION AND APPLICATION ON GAS-DRIVE DEVELOPMENT IN ULTRA-LOW PERMEABILITY RESERVOIRS

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Journal of Hydrodynamics 2008年第2期20卷 254-260页

作者： ZHAO Ming-guo ZHOU Hai-fei CHEN Ding-feng key laboratory of {2. oil and Gas recovery Minnistry of Education Daqing Petroleum Institute Daqing 163318 China

To select a proper displacement medium with the purpose of developing ultra-low permeability reservoirs both effectively and economically, three kinds of gases, including CO2. NG and N2. are studied through physical modeling and numerical simulation under the specified reservoir conditions. The results indicate that the oil recovery through water injection is relatively low in ultra-low permeability reservoirs, where the water breaks through early and the water cut rises rapidly. Gas injection can enhance the production, of which the gas-drive efficiency depends on the injection pressure and the gas itself. CO2.is proved to be the best one after comprehensive consideration of the recovery speed, the overall recovery efficiency and the time needed for gas to break through. The pressure of CO2.injection in the field experiments is lower, compared with that of water-drive. The injectivity index of CO2.is 7.2.times as high as that of water, and the oil production of the test well group increases by about 4 t/d.

关键词： ultra-low permeability reservoir gas drive physical modeling numerical simulation field experiment

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