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Chinese Journal Of Geochemistry 2010年第3期29卷 293-300页

作者： CAO Qiang YE Jiaren SHEN Chuanbo TANG Daqing key laboratory oftectonics and petroleum resources China University of Geosciences Ministry of Education Wuhan 430074 China

The Yitong Basin is an oilbearing basin with unique characteristics in Northeast China. On the basis of apatite fission track ages and geological relationship, the tectonic uplift history of the Yitong Basin since the Oligo-cene was discussed. Based on apatite fission track analysis of five samples from the Luxiang and Chaluhe fault depressions and basin modeling study, it can be concluded that since the Oligocene (36.6 Ma) in the Yitong Basin, the Chaluhe fault depression has undergone two episodes of uplift during 24.9-19.1 Ma and 6.9-4.9 Ma. And the Luxiang fault depression also had undergone two episodes of uplift during 30-27.8 Ma and 22.6-11.1 Ma. Moreover, the average apparent exhumation rates for the Chaluhe fault depression and Luxiang fault depression, could be calculated to be 70.34 and 60.33 m/Ma since 21.8 Ma and 18.9 Ma, respectively. The results of thermochronological analysis can also be supported by the evidence from geological relationships such as geodynamics, volcanic activity, and stratigraphic division and correlation.

关键词：裂变径迹年龄地质证据隆升历史盆地构造磷灰石渐新世东北中国

Coupled effects of stress damage and drilling fluid on strength of hard brittle shale

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Journal of Central South University 2016年第12期23卷 3256-3261页

作者：汪伟邓金根蔚宝华郑小锦闫传梁邓月 State key laboratory of petroleum resources and Prospecting China University of Petroleum

During well drilling process,original stress state of hard brittle shale will be changed due to stress redistribution and concentration,which leads to stress damage phenomenon around the ***,drilling fluid will invade into formation along the tiny cracks induced by stress damage,and then weaken the strength of hard brittle *** on this problem,a theoretical model was set up to discuss damage level of shale under uniaxial compression tests using acoustic velocity *** specifically,considering the coupled effect of stress damage and drilling fluid,the relationship between hard brittle shale strength and elapsed time was analyzed.

关键词： hard brittle shale stress damage drilling fluid time effect strength

Evaluation of gas wettability and its effects on fluid distribution and fluid flow in porous media

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petroleum Science 2013年第4期10卷 515-527页

作者： Jiang Guancheng Li Yingying Zhang Min State key laboratory of petroleum resources and Prospecting China University of Petroleum MOE key laboratory of petroleum Engineering China University of Petroleum

The special gas wettability phenomenon of reservoir rocks has been recognized by more and more *** has a significant effect on efficient development of unconventional ***,based on the preferentially gas-covered ability and surface free energy changes,definition and evaluation methods have been ***,a method for altering rock wettability and its mechanisms have been studied,surface oriented phenomena of functional groups with low surface energy are the fundamental reason for gas wettability alteration of ***,the effect of gas wettability on the surface energy,electrical properties and dilatability are ***,the effects of gas wettability on capillary pressure,oil/gas/water distribution and flow are investigated with capillary tubes and etchedglass network *** gas wettability theory of reservoir rocks has been initially established,which provides theoretical support for the efficient production of unconventional reservoirs and has great significance.

关键词： Gas-wetting fluorocarbon copolymer contact angle capillary pressure surface free energy surface property fluid flow in porous media

Simulation for the Controlling Factors of Structural Deformation in the Southern Margin of the Junggar Basin

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Acta Geologica Sinica(English Edition) 2012年第4期86卷 842-853页

作者： YU Fusheng LI Xiaojian LI Dinghua FENG Zicheng LI Xueliang State key laboratory of petroleum resources and Processing China University of Petroleum

According to the differences of structural deformation characteristics, the southern margin of the Junggar basin can be divided into two segments from east to west. Arcnate thrust-and-fold belts that protrude to the north are developed in the eastern segment. There are three rows of en echelon thrust-and-fold belts in the western segment. Thrust and fold structures of basement-involved styles are developed in the first row, and decollement fold structures are formed from the second row to the third row. In order to study the factors controlling the deformation of structures, sand-box experiments have been devised to simulate the evolution of plane and profile deformation. The planar simulation results indicate that the orthogonal compression coming from Bogeda Mountain and the oblique compression with an angle of 75° between the stress and the boundary originating from North Tianshan were responsible for the deformation differences between the eastern part and the western part. The Miquan-Uriimqi fault in the basement is the pre-existing condition for generating fragments from east to west. The profile simulation results show that the main factors controlling the deformation in the eastern part are related to the decollement of Jurassic coal beds alone, while those controlling the deformation in the western segment are related to both the Jurassic coal beds and the Eogene clay beds. The total amount of shortening from the Yaomoshan anticline to the Gumudi anticline in the eastern part is -19.57 km as estimated from the simulation results, and the shortening rate is about 36.46%; that from the Qingshuihe anticline to the Anjihai anticline in the western part is -22.01 km as estimated by the simulation results, with a shortening rate of about 32.48%. These estimated values obtained from the model results are very close to the values calculated by means of the balanced cross section.

关键词： characteristics of deformation thrust-and-fold belt decollement structure controlling factor sand-box simulation southern margin of the Junggar basin

Geochemical studies of the Silurian oil reservoir in the Well Shun-9 prospect area, Tarim Basin, NW China

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petroleum Science 2013年第4期10卷 432-441页

作者： Song Daofu Li Meijun Wang T.–G State key laboratory of petroleum resources and Prospecting China University of Petroleum

Commercial oil flow has been obtained from the sandstone reservoir of the Lower Silurian Kelpintag Formation in the Well Shun-9 prospect *** the present studies,10 Silurian oil and oil sand samples from six wells in the area were analyzed for their molecular and carbon isotopic compositions,oil alteration（biodegradation）,oil source rock correlation and oil reservoir filling *** the Silurian oils and oil sands are characterized by low Pr/Ph and C21/C23 tricyclic terpane（〈1.0） ratios,＂V＂-pattern C27-C29 steranes distribution,low C28-sterane and triaromatic dinosterane abundances and light δ13C values,which can be correlated well with the carbonate source rock of the O3 l Lianglitage *** oil biodegradation levels have also been confirmed for the different oils/oil sands *** the S1k2 seal,oils and oil sands from the S1k1 interval of the Kelpintag Formation have only suffered light biodegradation as confirmed by the presence of ＂UCM＂ and absence of 25-norhopanes,whereas the S1k3-1 oil sands were heavily biodegraded（proved by the presence of 25-norhopanes） due to the lack of the S1k2 seal,which suggests a significant role of the S1k2 seal in the protection of the Silurian oil *** on the Ts/（Ts＋Tm） and 4-/1-MDBT ratios as reservoir filling tracers,a general oil filling direction from NW to SE has been also estimated for the Silurian oil reservoir in the Well Shun-9 prospect area.

关键词： Silurian oil reservoir Well Shun-9 prospect area geochemistry oil source rock correlation alteration oil reservoir filing direction

Experimental investigation of shale imbibition capacity and the factors influencing loss of hydraulic fracturing fluids

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petroleum Science 2015年第4期12卷 636-650页

作者： Hong-Kui Ge Liu Yang Ying-Hao Shen Kai Ren Fan-Bao Meng Wen-Ming Ji Shan Wu State key laboratory of petroleum resources and Prospecting China University of Petroleum

Spontaneous imbibition of water-based frac- turing fluids into the shale matrix is considered to be the main mechanism responsible for the high volume of water loss during the flowback period. Understanding the matrix imbibition capacity and rate helps to determine the frac- turing fluid volume, optimize the flowback design, and to analyze the influences on the production of shale gas. Imbibition experiments were conducted on shale samples from the Sichuan Basin, and some tight sandstone samples from the Ordos Basin. Tight volcanic samples from the Songliao Basin were also investigated for comparison. The effects of porosity, clay minerals, surfactants, and KC1 solutions on the matrix imbibition capacity and rate were systematically investigated. The results show that the imbibition characteristic of tight rocks can be characterized by the imbibition curve shape, the imbibition capacity, the imbibition rate, and the diffusion rate. The driving forces of water imbibition are the capillary pressure and the clay absorption force. For the tight rocks with low clay contents, the imbibition capacity and rate are positively correlated with the porosity. For tight rocks with high clay content, the type and content of clay minerals are the most impor- tant factors affecting the imbibition capacity. The imbibed water volume normalized by the porosity increases with an increasing total clay content. Smectite and illite/smectite tend to greatly enhance the water imbibition capacity. Furthermore, clay-rich tight rocks can imbibe a volume of water greater than their measured pore volume. The aver- age ratio of the imbibed water volume to the pore volume is approximately 1.1 in the Niutitang shale, 1.9 in the Lujiaping shale, 2.8 in the Longmaxi shale, and 4.0 in the Yingcheng volcanic rock, and this ratio can be regarded as a parameter that indicates the influence of clay. In addition, surfactants can change the imbibition capacity due to alteration of the capillary pressure and

关键词： Imbibition . Shale Fracturing fluid Capillary pressure Clay

Properties and testing of a hydraulic pulse jet and its application in offshore drilling

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petroleum Science 2014年第3期11卷 401-407页

作者： Shi Huaizhong Li Gensheng Huang Zhongwei Shi Shuaishuai State key laboratory of petroleum resources and Prospecting China University of Petroleum

Offshore drilling has attracted more attention than ever before due to the increasing worldwide energy demand especially in China. High cost, long drilling cycles, and low rate of penetration （ROP） represent critical challenges for offshore drilling operations. The hydraulic pulse generator was specifically designed, based on China offshore drilling technologies and parameters, to overcome problems encountered during offshore drilling. Both laboratory and field tests were conducted to collect the characteristics of the hydraulic pulse generator. The relationships between flow rate and pressure amplitude, pressure loss and pulse frequency were obtained, which can be used to optimize operation parameters for hydraulic pulse jet drilling. Meanwhile a bottom hole assembly （BHA） for pulse jet drilling has been designed, combining the hydraulic pulse generator with the conventional BHA, positive displacement motor, and rotary steerable system （RSS） etc. Furthermore, the hydraulic pulse jet technique has been successfully applied in more than 10 offshore wells in China. The depth of the applied wells ranged from 2,000 m to 4,100 m with drilling bit diameters of 311 mm and 216 mm. The field application results showed that hydraulic pulse jet technique was feasible for various bit types and formations, and that ROP could be significantly increased, by more than 25%.

关键词： Pulse jet offshore drilling parameter test oilfield application rate of penetration

Greenhouse gas emissions from oilfield-produced water in Shengli Oilfield,Eastern China

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Journal of Environmental Sciences 2016年第8期28卷 101-108页

作者： Shuang Yang Wei Yang Guojun Chen Xuan Fang Chengfu Lv Jiaai Zhong Lianhua Xue key laboratory of petroleum resources Gansu Province/Key Laboratory of Petroleum Resources Research Institute of Geology and Geophysics Chinese Academy of Sciences University of Chinese Academy of Sciences

Greenhouse gas（GHG） emissions from oil and gas systems are an important component of the GHG emission inventory. To assess the carbon emissions from oilfield-produced water under atmospheric conditions correctly, in situ detection and simulation experiments were developed to study the natural release of GHG into the atmosphere in the Shengli Oilfield,the second largest oilfield in China. The results showed that methane（CH4） and carbon dioxide（CO2） were the primary gases released naturally from the oilfield-produced *** atmospheric temperature and release time played important roles in determining the CH4 and CO2emissions under atmospheric conditions. Higher temperatures enhanced the carbon emissions. The emissions of both CH4 and CO2from oilfield-produced water were highest at 27°C and lowest at 3°C. The bulk of CH4 and CO2was released from the oilfield-produced water during the first release period, 0–2 hr, for each temperature, with a maximum average emission rate of 0.415 g CH4/（m3·hr） and 3.934 g CO2/（m3·hr）, respectively. Then the carbon emissions at other time periods gradually decreased with the extension of time. The higher solubility of CO2 in water than CH4 results in a higher emission rate of CH4 than CO2over the same release duration. The simulation proved that oilfield-produced water is one of the potential emission sources that should be given great attention in oil and gas systems.

关键词： Methane Carbon dioxide Oilfield-produced water Atmospheric conditions

Giant negative photoresistance of epitaxial manganite La2/3Ca1/3MnO3-δ film

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Science China(Information Sciences) 2015年第12期58卷 204-210页

作者： XI JianFeng ZHAO Kun NI Hao XIANG WenFeng FENG Xin SUN Qi LU ZhiQing XIAO LiZhi State key laboratory of petroleum resources and Prospecting China University of Petroleum Beijing key laboratory of Optical Detection Technology for Oil and Gas China University of Petroleum

The La2/3Ca1/3Mn O3-δ film has been deposited on the(001) Sr Ti O3 substrate and its temperature-dependent photoconductive properties have been investigated from 80 to 300 K. The La2/3Ca1/3Mn O3-δfilm has a novel photoelectric property due to its oxygen-deficient structure. We observed laser-induced giant negative photoresistance of the sample in a wide temperature range. The change rate of negative photoresistance was nearly 100% at the low temperature when the sample was irradiated by 532 nm laser. In addition, this effect was sensitive to the power of laser irradiation. The oxygen-deficiency of La2/3Ca1/3Mn O3-δfilm seems to have an impact on the laser-induced resistance variation. The experimental results made the La2/3Ca1/3Mn O3-δfilm a promising application as a photoswitch device.

关键词： giant negative photoresistance oxygen-deficient photoswitch thin film manganite oxide

Settling behavior of non-spherical particles in power-law fluids:Experimental study and model development

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Particuology 2019年第5期17卷 30-39页

作者： Zhengming Xu Xianzhi Song Gensheng Li Zhaoyu Pang Zhaopeng Zhu State key laboratory of petroleum resources and Prospecting China University of Petroleum Beijing 102249 China

Solid-particle settling occurs in many natural and industrial processes, such as in the transportation of drilling cuttings and fracturing proppant. Knowledge of the drag coefficient and settling velocity of cuttings and proppant is of significance to hydraulics design, wellbore cleanout, and fracture optimization. We conducted 553 tests to investigate the settling characteristics of spherical and non-spherical particles in power-law fluids. Three major particle shapes (spherical, cubic, and cylindrical) and eight different particle sphericities were used to simulate cuttings and proppant, and power-law fluids were applied to simulate drilling and fracturing fluids. Based on the data analysis, a new drag coefficient-particle Reynolds number correlation was developed to determine the drag coefficient in a power-law fluid for spherical and non-spherical particles. The drag coefficient increases as the sphericity decreases for the same particle Reynolds number. For a specific particle shape, the drag coefficient decreases as the particle Reynolds number increases, but the decreasing trend is reduced at high particle Reynolds number conditions. An explicit settling-velocity equation was proposed to calculate the settling velocity of spherical and non-spherical particles in power-law fluids by considering the effect of sphericity. A suitable range for the proposed model is 0.0001 < Re <200, 0.471 <φ< 1, and 0.505 < n < 1. An illustrative example is presented to show how to calculate the drag coefficient and settling velocity in power-law fluids with given particle and fluid properties.

关键词： Settling velocity Drag coefficient Non-spherical particle Spherical particle Power-law fluids