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Organic petrology and hydrocarbon generation of potential source rocks in Permian formation of Junggar Basin,Northwest in China

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Journal of Central South University 2013年第6期20卷 1693-1702页

作者：秦黎明张枝焕 SINOPEC Research Institute of petroleum Engineering state key laboratory for petroleum Resource and prospecting(China University of petroleum)

From the outcrops in the Yaomoshan and Hongyanchi sections, oil shales, deep dark mudstones or black mudstones with better organic richness were found. Through the analysis of the samples in the organic petrology method, the microscope features of the sedimentary organic matter were studied. The results indicate that three types of kerogens present in the measured samples. Kerogen type I consists of the laminate algainite, abundant sporinite and only little content of cutinite, which can mainly generate oil. The generation hydrocarbon components of the type II kerogen are dominated by the sporinite, cutinite and little the exinite debris. The type III kerogen is comprised of the sporinite and debris of the exinite with some components of gas generation. Through the analysis of the experiments, the organic kerogen of the Lucaogou formation is mostly comprised of the type I, partially type II, and particularly type III. In Hongyanchi formation, the organic type is mixed by the types II and III. The plot of the （$1＋$2） or TOC value and the content of exinite show two trends. From the evolution of burial and the Permian source rocks in Changji Depression, the Permian formation source rock has ended the generation of hydrocarbon. A significant difference in constituents of the organic macerals among three kerogens in these samples leads to the distinction of the potential hydrocarbon generation. The Lucaogou formation for kerogen type I has better potential hydrocarbon generation. It can reach the oil peak with Ro ratio Of 0.9%. For the kerogen II, the oil peak of the source rocks comes late with the Ro ratio of 1.0% with less quantity of the generation hydrocarbon than the kerogen I. For type III, it can mainly generate gas and reach the gas peak with the Ro ratio of 1.3%. In a word, the Lucaogou formation and Hongyanchi formation source rocks with high organic richness in Permian source rocks have well exploration prospects.

关键词： organic macerals hydrocarbon generation potential Permian source rocks southern Junggar Basin

Advanced fluid-typing methods for NMR logging

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petroleum Science 2011年第2期8卷 163-169页

作者： Xie Ranhong Xiao Lizhi state key laboratory of petroleum Resource and prospecting China University of Petroleum Beijing 102249 China key laboratory of Earth prospecting and Information Technology China University of Petroleum Beijing 102249 China

In recent years, nuclear magnetic resonance （NMR） has been increasingly used for fluid- typing in well-logging because of the improved generations of NMR logging tools. This paper first discusses the applicable conditions of two one-dimensional NMR methods： the dual TW method and dual TE method. Then, the two-dimensional （T2, D） and （T2, T1） NMR methods are introduced. These different typing methods for hydrocarbon are compared and analyzed by numerical simulation. The results show that the dual TW method is not suitable for identifying a macroporous water layer. The dual TE method is not suitable for typing gas and irreducible water. （T2, T1） method is more effective in typing a gas layer. In an oil-bearing layer of movable water containing big pores, （T2, T1） method can solve the misinterpretation problem in the dual TWmethod between a water layer with big pores and an oil layer. The （T2, T1） method can distinguish irreducible water from oil of a medium viscosity, and the viscosity range of oil becomes wide in contrast with that of the dual TW method. The （T2, D） method is more effective in typing oil and water layers. In a gas layer, when the SNR is higher than a threshold, the （T2, D） method can resolve the overlapping T2 signals of irreducible water and gas that occurs due to the use of the dual TE method. Twodimensional NMR for fluid-typing is an important development of well logging technology.

关键词： NMR logging one-dimensional NMR two-dimensional NMR reservoir evaluation fluidtyping

Methane Adsorption Capacity Reduction Process of Water-Bearing Shale Samples and Its Influencing Factors: One Example of Silurian Longmaxi Formation Shale from the Southern Sichuan Basin in China

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Journal of Earth Science 2021年第4期32卷 946-959页

作者： Zhiye Gao Shuling Xiong state key laboratory of petroleum resources and prospecting China University of PetroleumBeijing 102249China Unconventional petroleum Research Institute China University of PetroleumBeijing 102249China

Due to the existence of water content in shale reservoir,it is quite meaningful to clarify the effect of water content on the methane adsorption capacity(MAC)of ***,the role of spatial configuration relationship between organic matter(OM)and clay minerals in the MAC reduction process is still *** Silurian Longmaxi Formation shale samples from the Southern Sichuan Basin in China were prepared at five relative humidity(RH)conditions(0%,16%,41%,76%,99%)and the methane adsorption experiments were conducted on these water-bearing shale samples to clarify the MAC reduction process considering the spatial configuration relationship between clay minerals and OM and establish the empirical model to fit the *** organic carbon(TOC)content and mineral compositions were analyzed and the pore structures of these shale samples were characterized by field-emission scanning electron microscopy(FE-SEM),N2 adsorption and high-pressure mercury intrusion porosimetry(HPMIP).The results showed that the MAC reduction of clay minerals in OM occurred at different RH conditions from that of clay minerals outside ***,the amount of MAC reduction of shale samples prepared at the same RH condition was negatively related with clay content,which indicated the protection role of clay minerals for the MAC of water-bearing shale *** MAC reduction process was generally divided into three stages for siliceous and clayey shale *** the MAC of OM started to decline during stage(1)for calcareous shale sample mainly because water could enter OM pores more smoothly through hydrophobic pathway provided by carbonate minerals than through hydrophilic clay mineral ***,this study will contribute to improving the evaluation method of shale gas reserve.

关键词： Longmaxi Formation shale water content OM-clay complexes methane adsorption capacity reduction

Chemical modification of barite for improving the performance of weighting materials for water-based drilling fluids

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petroleum Science 2024年第1期21卷 551-566页

作者： Li-Li Yang Ze-Yu Liu Shi-bo Wang Xian-Bo He Guan-Cheng Jiang Jie Zhang MOE key laboratory of petroleum Engineering State Key Laboratory of Petroleum Resources and ProspectingChina University of Petroleum(Beijing)Changping DistrictBeijing102249China MOE key CNPC Drilling Research Institute Changping DistrictBeijing102206China

With increasing drilling depth and large dosage of weighting materials,drilling fluids with high solid content are characterized by poor stability,high viscosity,large water loss,and thick mud cake,easier leading to reservoir damage and wellbore *** this paper,micronized barite(MB)was modified(mMB)by grafting with hydrophilic polymer onto the surface through the free radical polymerization to displace conventional API barite *** suspension stability of water-based drilling fluids(WBDFs)weighted with API barite:mMB=2:1 in 600 g was significantly enhanced compared with that with API barite/WBDFs,exhibiting the static sag factor within 0.54 and the whole stability index of *** viscosity and yield point reached the minimum,with a reduction of more than 40%compared with API barite only at the same *** multi-stage filling and dense accumulation of weighting materials and clays,filtration loss was decreased,mud cake quality was improved,and simultaneously it had great reservoir protection performance,and the permeability recovery rate reached 87%.In addition,it also effectively improved the lubricity of *** sticking coefficient of mud cake was reduced by 53.4%,and the friction coefficient was ***,mMB can serve as a versatile additive to control the density,rheology,filtration,and stability of WBDFs weighted with API barite,thus regulating comprehensive performance and achieving reservoir protection *** work opened up a new path for the productive drilling of extremely deep and intricate wells by providing an efficient method for managing the performance of high-density WBDFs.

关键词： Drilling fluids Weighting materials Filtration control Reservoir protection Stability property

Shaly detritus embedded epoxy-resin coated proppants

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petroleum Science 2022年第4期19卷 1735-1744页

作者： Zhao-Hui Lu Xiu-Ping Lan Yong Yuan Jian-Kun Zhou Si-Yuan Chen Fan Fan Ying-Chun Niu Shou-Zhen Li Kai-Yi Hu Yang Zhou Quan Xu key laboratory of Shale Gas Exploration Ministry of Natural ResourcesChongqing Institute of Geology and Mineral ResourcesChongqing401120China state key laboratory of petroleum resources and prospecting Bejing Key Laboratory of Biogas Upgrading UtlizationHarvard SEAS-CUPB Joint Laboratory on Petroleum ScienceChina University of Petroleum(Beijing)Beijing102249China

Proppant plays a significant role in the hydraulic fracturing process, which can affect the production of oil and gas wells. Due to the high density and low adhesion force, the settling speed of traditional proppants is fast, which will lead to the blockage of a crack channel. In this study, a proppant with double layer structure is fabricated by coating epoxy-resin and shaly detritus on ceramic proppants for the first time,respectively. The epoxy-resin enables the shaly detritus to be coated on the proppant successfully, which can provide a new method for shaly detritus treatment. The adhesive ability of shaly detritus and epoxyresin coated proppants(SEPs) is improved by 10.4% under the load force of 500 n N, which prolongs the time for the fracture to close. At the same time, the suspending ability of SEPs is two times higher than the uncoated proppants. Once the guar gum solution concentration is 0.3 wt%, the settling time of SEPs is36.7% longer than that of the uncoated proppants, which can effectively reduce the settlement of proppants in the crack. In addition, the hydrophobicity of the SEPs is enhanced, which reduces the wateroil ratio of crude oil and increases the liquid conductivity tested by deionized water. In summary, this new proppant is expected to promote the development of unconventional oil and gas resources.

关键词： Coated proppant Shaly detritus Hydrophobicity Conductivity

Pyrite-hydrocarbon Interaction under Hydrothermal Conditions: an Alternative Origin of H_2S and Organic Sulfur Compounds in Sedimentary Environments

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Acta Geologica Sinica(English Edition) 2016年第6期90卷 2133-2148页

作者： DING Kangle MEI Ping LUO Yue key laboratory of Exploration Technologies for Oil and Gas resources of Ministry of Education Yangtze University state key laboratory of petroleum resources and prospecting China University of Petroleum School of Chemistry and Environmental Engineering Yangtze University

Sulfate rocks and organic sulfur from sedimentary organic matter are conventionally assumed as the original sulfur sources for hydrogen sulfide （H2S） in oil and gas reservoirs. However, a few recent experiments preliminarily indicate that the association of pyrite and hydrocarbons may also have implications for H2S generation, in which water effects and natural controls on the evolution of pyrite sulfur into OSCs and H2S have not been evaluated. In this study, laboratory experiments were conducted from 200 to 450°C to investigate chemical interactions between pyrite and hydrocarbons under hydrothermal conditions. Based on the experimental results, preliminary mechanism and geochemical implications were tentatively discussed. Results of the experiments showed that decomposition of pyrite produced H2S and thiophenes at as low as 330°C in the presence of water and n-pentane. High concentrations of H2S were generated above 450°C under closed pyrolysis conditions no matter whether there is water in the designed experiments. However, much more organic sulfur compounds （OSCs） were formed in the hydrous pyrolysis than in anhydrous pyrolysis. Generally, most of sulfur liberated from pyrite at elevated temperatures was converted to H2S. Water was beneficial to breakdown of pyrite and to decomposition of alkanes into olefins but not essential to formation of large amounts of H2S, given the main hydrogen source derived from hydrocarbons. In addition, cracking of pyrite in the presence of 1-octene under hydrous conditions was found to proceed at 200°C, producing thiols and alkyl sulfides. Unsaturated hydrocarbons would be more reactive intermediates involved in the breakdown of pyrite than alkanes. The geochemistry of OSCs is actually controlled by various geochemical factors such as thermal maturity and the carbon chain length of the alkanes. This study indicates that the scale of H2S gas generated in deep buried carbonate reservoirs via interactions between pyrite and natural

关键词： laboratory experiments pyrite hydrocarbon H2S OSCs geochemical implications

Numerical analysis of the effects of downhole dynamic conditions on formation testing while drilling

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petroleum Science 2014年第3期11卷 391-400页

作者： DI Dejia TAO Guo WANG Bing CHEN Xu SUN Jiming state key laboratory of petroleum resources and prospecting China University of Petroleum SINOPEC Research Institute of petroleum Engineering Departments of petroleum Geosciences & Engineering The Petroleum InstituteAbu Dhabi UAE

Formation testing while drilling is an innovative technique that is replacing conventional pressure testing in which the fluid sampling is conducted in a relatively short time following the drilling. At this time, mud invasion has just started, mudcake has not formed entirely and the formation pressure is not stable. Therefore, it is important to study the influence of the downhole dynamic environment on pressure testing and fluid sampling. This paper applies an oil-water two phase finite element model to study the influence of mudcake quality and mud filtrate invasion on supercharge pressure, pretest and sampling in the reservoirs of different permeability. However, the study is only for the cases with water based mud in the wellbore. The results illustrate that the mudcake quality has a significant influence on the supercharge pressure and fluid sampling, while the level of mud filtrate invasion has a strong impact on pressure testing and sampling. In addition, in-situ formation pressure testing is more difficult in low permeability reservoirs as the mud filtrate invasion is deeper and therefore degrades the quality of fluid sampling. Finally, a field example from an oil field on the Alaskan North Slope is presented to validate the numerical studies of the effects of downhole dynamic conditions on formation testing while drilling.

关键词： Formation testing while drilling formation supercharge pressure testing fluid sampling,finite element method mudcake filtrate invasion

Introduction to the special issue of unconventional hydrocarbon research

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petroleum Science 2015年第4期12卷 561-562页

作者： Yan Song state key laboratory of petroleum resources and prospecting China University of Petroleum Unconventional Natural Gas Institute China University of Petroleum

Unconventional hydrocarbon research has developed rapidly in the recent years. In order to review the advances in unconventional hydrocarbon research in the areas of reservoir geology, geophysics, engineering, and economic evaluation, the Unconventional Natural Gas Institute （UNGI） of China University of petroleum （Beijing） was invited to organize this special issue. Papers in this special issue are mainly about tight oil and gas, shale oil and gas, and coalbed methane, which are the main types of unconventional hydrocarbon.

关键词： hydrocarbon reservoir shale geology petroleum fracturing advances methane sandstone fractured

A Quantitative Evaluation of Shale Gas Content in Different Occurrence states of the Longmaxi Formation: A New Insight from Well JY-A in the Fuling Shale Gas Field,Sichuan Basin

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Acta Geologica Sinica(English Edition) 2019年第2期93卷 400-419页

作者： TANG Ling SONG Yan LI Qianwen PANG Xiongqi JIANG Zhenxue LI Zhuo TANG Xianglu YU Hailong SUN Yue FAN Shichao ZHU Lin state key laboratory of petroleum resources and prospecting China University of Petroleum The Unconventional Natural Gas Institute China University of Petroleum Sinopec petroleum Exploration and Production Research Institute

Comprehensive quantitative evaluation of shale gas content and the controlling factors in different occurrence states is of great significance for accurately assessing gas-bearing capacity and providing effective well-production strategies. A total of 122 core samples from well JY-A in the Fuling shale gas field were studied to reveal the characteristics of S_1 l shale,15 of which were selected to further predict the shale gas content in different occurrence states, which are dependent on geological factors in the thermal evolution process. Geological parameters were researched by a number of laboratory programs, and the factors influential in controlling shale gas content were extracted by both PCA and GRA methods and prediction models were confirmed by the BE method using SPSS software. Results reveal that the adsorbed gas content is mainly controlled by TOC, Ro, SSA, PD and pyrite content, and the free gas content is mainly controlled by S_2, quartz content, gas saturation and formation pressure for S_1 l in well JY-A. Three methods, including the on-site gas desorption method, the empirical formula method, and the multiple regression analysis method were used in combination to evaluate the shale gas capacity of well JY-A, all of which show that the overall shale gas content of well JY-A is in the range of 2.0–5.0 m^3/t and that the free gas ratio is about 50%, lower than that of well JY-1. Cause analysis further confirms the tectonics and preservation conditions of S_1 l in the geological processes, especially the influence of eastern boundary faults on well JY-A, as the fundamental reasons for the differences in shale gas enrichment in the Jiaoshiba area.

关键词： shale gas content on-site gas desorption multiple regression analysis controlling factors Longmaxi shales Fuling shale gas field Jiaoshiba area