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Residual oil evolution based on displacement characteristic curve

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International Journal of Mining Science and Technology 2020年第3期30卷 337-343页

作者： Duanchuan Lyu Chengyan Lin Lihua Ren Chunmei Dong Jinpeng Song School of Geosciences China University of Petroleum(East China)QingdaoShandong 266580China Exploration Department of tarim oilfield company PetroChinaKorlaXinjiang 841000China

The purpose of this study was to determine the displacement and dynamic distribution characteristics of the remaining oil in the two development stages of water flooding and subsequent alkaline surfactant polymer(ASP) flooding. The well pattern types in the water and ASP flooding stages are a longdistance determinant well pattern and short-distance five-point well pattern, respectively. The type A displacement characteristic curve can be obtained using the production data, and the slope of the straight-line section of the curve can reflect the displacement strength of the oil displacement agent. A numerical simulation was carried out based on the geological model. The results revealed that the injected water advances steadily with a large-distance determinant water-flooding well pattern. The single-well water production rate increases monotonically during water flooding. There is a significant positive correlation between the cumulative water-oil ratio and the formation parameter. Differential seepage between the oil and water phases is the main factor causing residual oil formation after water flooding, while the residual oil is still relatively concentrated. The effect of the chemical oildisplacement agent on improving the oil-water two-phase seepage flow has distinct stages during ASP flooding. The remaining oil production is extremely sporadic after ASP flooding.

关键词： Water flooding ASP flooding Water-drive characteristic curve Residue oil Thick oil layer

Enhancement of the imbibition recovery by surfactants in tight oil reservoirs

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Petroleum Science 2018年第4期15卷 783-793页

作者： Zhan Meng Sheng-Lai Yang Yan Cui Zi-Yao Zhong Cheng-Gang Liang Lu Wang Kun Qian Quan-Zheng Ma Jun-Ru Wang Key Laboratory of Petroleum Engineering of the Ministry of Education China University of PetroleumBeijing Changqing oilfield company PetroChina Xinjiang oilfield company PetroChina

Hydraulic fracturing technology can significantly increase oil production from tight oil formations, but performance data show that production declines rapidly. In the long term, it is necessary to increase the development efficiency of block matrix, surfactant-aided imbibition is a potential way. The current work aimed to explain comprehensively how surfactants can enhance the imbibition rate. Laboratory experiments were performed to investigate the effects of wettability, interfacial tension(IFT), and relative permeability as the key parameters underlying surfactant solution imbibition. Two different types of surfactants, sodium dodecyl sulfate and polyethylene glycol octylphenol ether, at varied concentrations were tested on reservoir rocks. Experimental results showed that the oil recovery rate increased with increased wettability alteration and IFT and decreased residual oil saturation. A mechanistic simulator developed in previous studies was used to perform parametric analysis after successful laboratory-scale validation. Results were proven by parametric studies. This study,which examined the mechanism and factors influencing surfactant solution imbibition, can improve understanding of surfactant-aided imbibition and surfactant screening.

关键词： Spontaneous imbibition Tight oil reservoir Surfactants Wettability alteration Enhanced oil recovery

Relationship between the later strong gas-charging and the improvement of the reservoir capacity in deep Ordovician carbonate reservoir in Tazhong area, tarim Basin

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Chinese Science Bulletin 2009年第17期54卷 3076-3089页

作者： ZHAO WenZhi ZHU GuangYou ZHANG ShuiChang ZHAO XueFeng SUN YuShan WANG HongJun YANG HaiJun HAN JianFa Research Institute of Petroleum Exploration and Development PetroChina Beijing 100083 China Research Institute of Petroleum Exploration and Development Tarim Oilfield Company PetroChina Korla 841000 China

Some large-scale oil-gas fields have recently been discovered in marine carbonate in China, especially the significant discoveries in deep reservoir that reveals a favorable exploration prospect. Tazhong area is the first-order tectonic unit in tarim Basin, where there are nearly trillion cubic meters of natural gas resources in the Ordovician limestone reef flat complex in Lianglitage Formation. The reservoir is shelf edge reef flat complex, characterized by ultra-low porosity, low permeability and strong heterogeneous, with a current burial depth of 4500―6500 m. Studies find that the formation and distribution of deep reservoir of the Lianglitage Formation were controlled not only by the early high-energy sedimentary facies and corrosion, but the fracture network formed by the strong gas-charging process since the Himalayan epoch, which played an important role in optimizing and improving reservoir properties. This paper discusses the relationship between the strong later gas-charging and the improvement of the reservoir capacity in deep Ordovician carbonate reservoir, and also builts the corresponding mechanisms and modes, which is favorable for the prediction and evaluation of the advantageous exploration targets.

关键词：碳酸盐岩储层塔里木盆地塔中地区煤气收费奥陶系天然气资源能力勘探前景

Control of hydrocarbon accumulation by Lower Paleozoic cap rocks in the Tazhong Low Rise, Central Uplift, tarim Basin, West China

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Petroleum Science 2014年第1期11卷 67-80页

作者： Zhang Yanping Lü Xiuxiang Yang Haijun Han Jianfa Lan Xiaodong Zhao Yue Zhang Jinhui College of Geosciences China University of Petroleum State Key Laboratory of Petroleum Resources and Prospecting China University of Petroleum tarim oilfield company PetroChina CNOOC Tianjin Branch company

Despite the absence of regional cap rocks in the Lower Paleozoic for the entire Tazhong Low Rise,several sets of effective local cap rocks are well preserved on the Northern *** these the best is the Ordovician mudstone of the Sangtamu Formation; the second is the Silurian Red Mudstone Member of the Tatairtag Formation and the marl of the Ordovician Lianglitag Formation; and the third is the gray mudstone of the Silurian Kepingtag *** dense limestone of the Ordovician Yingshan Formation and the gypsum of the Middle Cambrian have shown initial sealing *** effective cap rocks are closely related to the distribution of Lower Palaeozoic hydrocarbons in the Tazhong Low *** well-preserved Sangtamu Formation mudstone and its location close to migration pathways,rich Lower Paleozoic hydrocarbon accumulation can be found on the Northem ***,most of the reserves are distributed below the Sangtamu Formation mudstone; areally,hydrocarbons are mainly found in the areas with well-developed Sangtamu Formation mudstone and Lianglitag Formation *** history and hydrocarbon charging history show that the evolution of Lower Palaeozoic cap rocks controlled the accumulation of hydrocarbon in the Tazhong Low *** the Red Mudstone Member of the Tatairtag Formation and Sangtamu Formation mudstone for examples：1） In the hydrocarbon charging time of the Late Caledonian-Early Hercynian,with top surfaces at burial depths of over 1,100 m,the cap rocks were able to seal oil and gas; 2） During the intense uplifting of the Devonian,the cap rocks with top surfaces at burial depths of 200-800 m and 500-1,100 m respectively were denuded in local areas,thus hydrocarbons trapped in earlier time were degraded to widespread bitumen; 3） In the hydrocarbon charging time of the Late Hercynian and Himalayan,the top surfaces of the cap rocks were at burial depths of over 2,000 m without intense uplifting and denudation thereafter,so trapped hydrocarbons

关键词： Cap rock hydrocarbon accumulation hydrocarbon destruction Lower Paleozoic Tazhong Low Rise

Why Can China Realize the Continental“Shale Oil Revolution”?

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Journal of Earth Science 2022年第5期33卷 1324-1327页

作者： Caineng Zou Zhi Yang Guoxin Li Jianzhong Li Xianyang Liu Yong Tang Tao Jiang Yu Yang Xuefeng Bai Songqi Pan Minghui Lu Zhengdong Lei Bo Cai petrochina Research Institute of Petroleum Exploration and Development Beijing 100083China petrochina Qinghai oilfield company Dunhuang 736202China petrochina Tuha oilfield company Hami 839009China petrochina Changqing oilfield company Xi'an 710018China petrochina Xinjiang oilfield company Karamay834000China petrochina Jilin oilfield company Songyuan138000China petrochina Southwest Oil and gas field company Chengdu610000China petrochina Daqing oilfield Comapny Ltd. Daqing163712China

0 INTRODUCTION Continental shale oil is a strategic alternative resource to ensure the safety of national oil supply and improve the level of industrial *** is a large country of continental oil resources,accounting for 90%of the total onshore oil resources;and China is also a major producer of continental oil,accounting for about 93%of the total oil production(Yang et al.,2019;Jia et al.,2018).

关键词： Continental shale accounting

Classification of carbonate gas condensate reservoirs using well test and production data analyses

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Petroleum Science 2011年第1期8卷 70-78页

作者： Li Yong Li Baozhu Hu Yongle Xia Jing Liu Zhaowei Deng Xingliang She Zhicheng Fan Kun Research Institute of Petroleum Exploration and Development PetroChinaBeijing 100083.China China National Oil ＆ Gas Exploration and Development Corporation PetroChinaBeijing 100034China tarim oilfield company PetroChinaKorlaXingjiang 841000China

Carbonate reservoir patterns play an important role in the production performance of oil and gas wells,and it is usually classified through static data analysis which cannot reflect the actual well *** paper takes the Tazhong No.1 gas field in the tarim Basin,China as an example to investigate the classification of carbonate *** classification method mainly combines well test analysis with production analysis—especially the Blasingame type curve *** on the characteristics of type curves for well test analysis and the Blasingame method,the relationship between the type curves and reservoir pattern was *** than 20 wells were analyzed and the reservoirs were classified into 3 major patterns with 7 ***,the classification results were validated by dynamic performance analysis of wells in the Tazhong No.1 gas *** the basis of the classification results,well stimulation（*** flooding in a single well） was carried out in three volatile-oil wells,and the oil recovery increased by up to 20%.

关键词： Carbonate reservoir pattern well test analysis production analysis type curve

Distribution and geochemical significance of phenylphenanthrenes and their isomers in selected oils and rock extracts from the tarim Basin,NW China

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Petroleum Science 2016年第2期13卷 183-191页

作者： Shao-Ying Huang Mei-Jun Li Ke Zhang T.-G.Wang Zhong-Yao Xiao Rong-Hui Fang Bao-Shou Zhang Dao-Wei Wang Qing Zhao Fu-Lin Yang Research Institute of Petroleum Exploration and Development Tarim Oilfield CompanyPetroChina State Key Laboratory of Petroleum Resources and Prospecting College of GeosciencesChina University of Petroleum

Twenty-two oil samples and eight source rock samples collected from the tarim Basin, NW China were geochemically analyzed to investigate the occurrence and distribution of phenylphenanthrene （PhP）, phenylanthracene （PhA）, and binaphthyl （BIN） isomers and methylphenanthrene （MP） isomers in oils and rock extracts with different deposi- tional environments. Phenylphenanthrenes are present in significant abundance in Mesozoic lacustrine mudstones and related oils. The relative concentrations of PhPs are quite low or below detection limit by routine gas chromatogxaphy-mass spectrometry （GC-MS） in Ordovician oils derived from marine carbonates. The ratio of 3-PhP/3-MP was used in this study to describe the relative abundance of phenylphenanthrenes to their alkylated counterparts--methylphenanthrenes. The Ordovician oils in the Tabei Uplift have quite low 3-PhP/3-MP ratios （〈0.10）, indicating their marine carbonate origin, associating with low Pr/Ph ratios （pristane/phytane）, high ADBT/ ADBF values （relative abundance of alkylated dibenzothiophenes to alkylated dibenzofurans）, low C30 diahopane/C3o hopane ratios, and low Ts/（Ts ＋ Tm）（18α-22, 29, 30-trisnorneohopane/（18α-22, 29, 30-trisnorneohopane ＋ 17α-22, 29, 30-trisnorhopane）） values. In contrast, the oils from Mesozoic and Paleogene sandstone reservoirs and related Mesozoic lacustrine mudstones have relatively higher 3-PhP/3-MP ratios （〉0.10）, associating with high Pr/Ph, low ADBT/ ADBF, high Ts/（Ts ＋ Tm）, and C30 diahopane/C30 hopane ratios. Therefore, the occurrence of significant amounts of phenylphenanthrenes in oils typically indicates that the organic matter of the source rocks was deposited in a suboxic envi- ronment with mudstone deposition. The phenylphenanthrenes may be effective molecular markers, indicating depositional environment and lithology of source rocks.

关键词： Phenylphenanthrene Methylphenanthrene Depositional environment Source rock

Synthesis and Solution Properties of Comb-like Acrylamide Copolymers

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Journal of Wuhan University of Technology(Materials Science) 2012年第6期27卷 1105-1109页

作者：罗霄 BAI Lei ZA Kejian LI Dongwen HAN Wei PU Xiaolin School of Petroleum Engineering Southwest Petroleum UniversityChengdu 610500China Research Institute of Petroleum Exploration and Development Xinjiang Oilfield CompanyPetroChinaKaramay 834000China tarim oilfield company Korla 841000China

A comb-like acrylamide copolymer （HCJ-1） was synthesized by using aqueous free radical polymerization of acrylamide （AM） as main monomer and ether carboxylate as functional monomer. The copolymers were characterized with FT-IR and SEM. The SEM results show that the molecular structure of copolymer is extended in salt water. It is proved that the copolymer shows good salt *** solution properties of HCJ-1 were studied and compared with those of partially hydrolyzed polyacrylamide （HPAM）. The experimental results show that the obtained HCJ-1, compared with HPAM, exhibits a dramatic enhancement in the salt-resistant properties. The apparent viscosity retention rate of 1.5 g/L HCJ-1 aqueous solution and salt solution after 180 days at 60 ℃ are 70.6% and 64.5%, respectively, exhibiting good thermal stability. In addition, HCJ-1 solution also displays the excellent shearing resistance. In a word, the experimental results show the HCJ-1 is a promising profiling agent for high salinity reservoir.

关键词： comb-like salt resistance thermal stability sheafing resistance

Theoretical exploration of water injection gravity flooding oil in ultra-deep fault-controlled fractured-cavity carbonate reservoirs

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Petroleum Exploration and Development 2022年第1期49卷 133-143页

作者： YANG Xuewen WANG Rujun DENG Xingliang LI Shiyin ZHANG Hui YAO Chao petrochina tarim oilfield company Korla 841000China

Based on the analysis of geological characteristics of ultra-deep fault-controlled fracture-cavity carbonate reservoirs and division of reservoir units, two physical models were made, and physical simulations of oil displacement by water injection were carried out to find out water flooding mechanism in the fault-controlled fracture-cavity carbonate reservoir under complex flow state. On this basis, a mathematical model of fault-controlled carbonate reservoir with coexisting seepage and free flow has been established. Pilot water injection tests have been carried out to evaluate the effects of enhancing oil recovery by water injection. The results show that: fault-controlled fracture-cavity carbonate reservoir units can be divided into three types:the strong natural energy connected type, the weak natural energy connected type and the weak natural energy isolated type;the fault-fracture activity index of the fault-controlled fractured-cavity body can effectively characterize the connectivity of the reservoir and predict the effective direction of water injection;the mathematical model of fault-controlled carbonate reservoir with coexisting seepage and free flows can quantitatively describe the fluid flow law in the fracture-cavity body;the water injected into the fault-controlled fracture-cavity body is weakly affected by the capillary force of the lithologic body, and the oil-water movement is mainly dominated by gravity. The development modes of single well water injection, unit water injection,and single well high pressure water injection proposed based on the connection structure of fracture-cavity space and well storage space configuration are confirmed effective by pilot tests, with obvious water injection gravity flooding effect.

关键词： tarim Basin Ordovician fault-controlled carbonate reservoir fractured-cavity carbonate reservoir water flooding gravity flooding EOR