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Micro-pore structure and oil displacement mechanism analysis for deep zone and low permeability reservoir in Mobei oilfield

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Petroleum Research 2018年第2期3卷 159-164页

作者： Haibin Su Ninghong Jia Yandong Yang Zhigang Wang Zhibin Jiang Lijuan Feng Jiru Yang Weifeng Lv PetroChina Xinjiang Oilfield Research Institute of Exploration and DevelopmentKaramayXinjiang843000China State Key Laboratory of Enhance Oil Recovery PetroChina Research Institute of Petroleum Exploration and DevelopmentBeijing100083China Department of Petroleum Engineering China University of Petroleum(Beijing)Beijing102249China Engineering Technology Research Institute of Xinjiang Oilfield Company KaramayXinjiang843000China Department of Polymer Science and Engineering School of Chemistry and Chemical EngineeringNanjing UniversityNanjing210046China

The Mobei reservoir is a low-permeability-sandstone reservoir,due to differences in pore geometry,it can be divided into two independent reservoirs:A1 reservoir and A2 *** better understanding the water flooding development effects of Mobei reservoir,the mercury intrusion porosimetry,water flooding CT scanning and micro-CT scanning experiments are used in this *** result shows that the reservoir has the strong heterogeneity which is weaken gradually from A1 reservoir to A2 *** pore radius is mainly distributed in the 100e200 microns,the throat radius is mainly distributed in the 1e3 *** water flooding core experiment in each reservoir shows a short water-free oil production period and rapid water cut after *** A2 reservoir core flooding process is similar to piston displacement,the A1 reservoir core flooding process refers to the phenomenon(The fingering phenomenon in the process of core flooding in the A1 reservoir is obvious).The calculated water drive efficiency of the A2 reservoir is 61.2%,which is higher than 49.1%of the A1 *** to the CT scanning process,the Mobei oilfield has low micro displacement efficiency and the A1 reservoir has a smaller spread(sweep area)and higher residual oil saturation.

关键词： low permeability reservoir Oil displacement efficiency CT scanning Micro-CT Mobei oilfield

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Test evaluation for vertical fracture wells in low permeability reservoir

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Journal of Energy and Power Engineering 2009年第9期2卷 32-35页

作者： CUI Li-ping HE Shun-li MOE Key Laboratory for Petroleum Engineering China University of Petroleum Beo＇ing 102249 China

As flow environment is poor in low permeability reservoirs, wells are always fractured in order to gain better economic benefits. Well testing analysis is very necessary for fracturing wells. However, available test analysis methods are of slow fitting speed and low fitting precision. In this paper, we first use a comprehensive evaluation method of analytical well testing, numerical well testing and well testing design. Many dynamic parameters such as fracture length, fracture conductivity, skin factor, etc are obtained. An example to illustrate accurate results of this method is given.

关键词： test evaluation fracture wells low permeability reservoir fracturing effect

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Model building for Chang-8 low permeability sandstone reservoir in the Yanchang formation of the Xifeng oil field

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Mining Science and Technology 2009年第2期19卷 245-251页

作者： SONG Fan HOU Jia-gen SU Ni-na School of Resources and Information China University of Petroleum Beijing 102249 China

In order to build a model for the Chang-8 low permeability sandstone reservoir in the Yanchang formation of the Xifeng oil field,we studied sedimentation and diagenesis of sandstone and analyzed major factors controlling this low permeability *** doing so,we have made clear that the spatial distribution of reservoir attribute parameters is controlled by the spatial distribution of various kinds of sandstone *** taking advantage of many coring wells and high quality logging data,we used regression analysis for a single well with geological conditions as constraints,to build the interpretation model for logging data and to calculate attribute parameters for a single well,which ensured accuracy of the 1-D vertical *** this basis,we built a litho-facies model to replace the sedimentary facies *** addition,we also built a porosity model by using a sequential Gaussian simulation with the lithofacies model as the *** the end,we built a permeability model by using Markov-Bayes simula-tion,with the porosity attribute as the *** results show that the permeability model reflects very well the relative differences between low permeability values,which is of great importance for locating high permeability zones and forecasting zones favorable for exploration and exploitation.

关键词： Xifeng oil field low permeability reservoir attribute parameter Markov-Bayes model permeability model

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EFFECT OF A MOVING BOUNDARY ON THE FLUID TRANSIENT Flow IN low permeability reservoirS

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Journal of Hydrodynamics 2012年第3期24卷 391-398页

作者： LUO Wan-Jing WANG Xiao-dong School of Energy Resources China University of Geosciences Beijing 100083 China

In a low permeability reservoir, the existence of a moving boundary is considered in the study of the transient porous flow with threshold pressure gradient. The transmission of the moving boundary directly indicates the size of the drainage area as well as the apparent influences on the pressure behavior. The nonlinear transient flow mathematical model in which the threshold pressure gradient and the moving boundary are incorporated is solved by advanced mathematical methods. This paper presents some new analytical solutions describing the pressure distribution at a constant rate and the production decline in a constant pressure production with the boundary propagation. It is shown that the greater the threshold pressure gradient, the slower the transmission of the moving boundary, the larger the pressure loss will be, and there is no radial flow in the middle and later phases of the wellface pressure for a well at a constant rate. We have the the maximum moving boundary at a specific drawdown pressure for a low permeability reservoir The greater the threshold pressure gradient, the smaller the maximum moving boundary distance, the quicker the production decline for a well in a constant pressure production will be. The type curve charts for the modern well test analysis and the rate transient analysis with a moving boundary are obtained and the field test and the production data are interpreted as examples to illustrate how to use our new results.

关键词： threshold pressure gradient moving boundary well test analysis low permeability reservoir rate transient analysis

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Advances in enhanced oil recovery technologies for low permeability reservoirs

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Petroleum Science 2022年第4期19卷 1622-1640页

作者： Wan-Li Kang Bo-Bo Zhou Miras Issakhov Marabek Gabdullin Key Laboratory of Unconventional Oil&Gas Development(China University of Petroleum(East China)) Ministry of EducationQingdao266580ShandongPR China School of Petroleum Engineering China University of Petroleum(East China)Qingdao266580ShandongPR China Kazakh-British Technical University Almaty050000Kazakhstan

low permeability oil and gas resources are rich and have great potential all over the world, which has gradually become the main goal of oil and gas development. However, after traditional primary and secondary exploitation, there is still a large amount of remaining oil that has not been ***, in recent years, enhanced oil recovery(EOR) technologies for low permeability reservoirs have been greatly developed to further improve crude oil production. This study presents a comprehensive review of EOR technologies in low permeability reservoirs with an emphasis on gas flooding, surfactant flooding, nanofluid flooding and imbibition EOR technologies. In addition, two kinds of gel systems are introduced for conformance control in low permeability reservoirs with channeling problems. Finally,the technical challenges, directions and outlooks of EOR in low permeability reservoirs are addressed.

关键词： Enhanced oil recovery low permeability reservoir Gas flooding Surfactant flooding Nanofluid flooding Imbibition Conformance control

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A novel profile modification HPF-Co gel satisfied with fractured low permeability reservoirs in high temperature and high salinity

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Petroleum Science 2024年第1期21卷 683-693页

作者： Ya-Kai Li Ji-Rui Hou Wei-Peng Wu Ming Qu Tuo Liang Wei-Xin Zhong Yu-Chen Wen Hai-Tong Sun Yi-Nuo Pan China University of Petroleum Beijing Beijing102249China PetroChina Tarim Oilfield Company Korla 841000XinjiangChina Key Laboratory of Improving Oil and Gas Recovery of Ministry of Education Northeast Petroleum University Daqing 163318HeilongjiangChina Xi'an Shiyou University Xi'an 710065ShaanxiChina Northwest Oilfield Company SINOPECUrumqi 830011XinjiangChina

Conformance control and water plugging are a widely used EOR method in mature ***,majority of conformance control and water plugging agents are unavoidable dehydrated situation in high-temperature and high-salinity low permeability ***,a novel conformance control system HPF-Co gel,based on high-temperature stabilizer(CoCl_(2)·H_(2)O,CCH)is *** HPF-Co bulk gel has better performances with high temperature(120℃)and high salinity(1×10^(5)mg/L).According to Sydansk coding system,the gel strength of HPF-Co with CCH is increased to code *** dehydration rate of HPF-Co gel is 32.0%after aging for 150 d at 120℃,showing excellent thermal *** rheological properties of HPF gel and HPF-Co gel are also *** results show that the storage modulus(G′)of HPF-Co gel is always greater than that of HPF *** effect of CCH on the microstructure of the gel is *** results show that the HPF-Co gel with CCH has a denser gel network,and the diameter of the three-dimensional network skeleton is 1.5-3.5μ*** 90 d of aging,HPF-Co gel still has a good three-dimensional *** spectroscopy results show that CCH forms coordination bonds with N and O atoms in the gel amide group,which can suppress the vibration of cross-linked sites and improve the stability at high *** core plugging test determines the optimized polymer gel injection strategy and injection velocity with HPF-Co bulk gel system,plugging rate exceeding 98%.Moreover,the results of subsequent waterflooding recovery can be improved by 17%.

关键词： low permeability reservoir High-temperature resistant gel Complexation reaction Polymer gel injection strategy Plugging rate Enhanced oil recovery

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A streamline approach for identification of the flowing and stagnant zones for five-spot well patterns in low permeability reservoirs

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Journal of Hydrodynamics 2013年第5期25卷 710-717页

作者：罗万静王军磊王晓冬周英芳 School of Energy China University of Geosciences Petro China Research Institute of Petroleum Exploration and Development International Research Institute of Stavanger

The mechanism of the fluid flow in low permeability reservoirs is different from that in middle-high permeability reservoirs because of the existence of the Threshold Pressure Gradient （TPG）. When the pressure gradient at some location is greater than the TPG, the fluid in porous media begins to flow. By applying the mirror image method and the principle of potential superposition, the steady-state pressure distribution and the stream function for infinite five-spot well patterns can be obtained for a low permeability reservoir with the TPG effect. Based on the streamlines distribution, the flowing and stagnant zones in five-spot well patterns can be clearly seen. By the definition of the effective startup coefficient （SUC）, the ratio of the flowing and stagnant zones can be calculated accurately. It is shown that the SUC for five-spot well patterns is not constant, but decreases with the increase of the di- mensionless TPG. By increasing the effective permeability of the formation （such as by the acid treatment and the hydraulic fracture）, in increasing the injection-production differential pressure or shortening the well space （such as by infilling well）, the SUC can be improved. The results of the sensitivity analysis show that a better choice for the SUC enhancement is to shorten the well spacing for small permeability reservoirs and to increase the pressure difference for large permeability reservoirs. This streamline approach can be used to determine the distribution of remaining oil and provide guidance for infilling well.

关键词： low permeability reservoir Threshold Pressure Gradient (TPG) streamlines simulation five-spot well patterns effective startup coefficient

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Synergistic anionic/zwitterionic mixed surfactant system with high emulsification efficiency for enhanced oil recovery in low permeability reservoirs

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Petroleum Science 2024年第2期21卷 936-950页

作者： Hai-Rong Wu Rong Tan Shi-Ping Hong Qiong Zhou Bang-Yu Liu Jia-Wei Chang Tian-Fang Luan Ning Kang Ji-Rui Hou National Key Laboratory of Petroleum Resources and Engineering China University of Petroleum-BeijingBeijing102249China Unconventional Petroleum Research Institute China University of Petroleum-BeijingBeijing102249China Gas Production Plant 5 of PetroChina Changqing Oilfield Company PetroChinaXi'an710000ShaanxiChina College of Petroleum Engineering China University of Petroleum-BeijingBeijing102249China College of Science China University of Petroleum-BeijingBeijing102249China Kazakh-British Technical University Almaty050000Kazakhstan

Emulsification is one of the important mechanisms of surfactant flooding. To improve oil recovery for low permeability reservoirs, a highly efficient emulsification oil flooding system consisting of anionic surfactant sodium alkyl glucosyl hydroxypropyl sulfonate(APGSHS) and zwitterionic surfactant octadecyl betaine(BS-18) is proposed. The performance of APGSHS/BS-18 mixed surfactant system was evaluated in terms of interfacial tension, emulsification capability, emulsion size and distribution, wettability alteration, temperature-resistance and salt-resistance. The emulsification speed was used to evaluate the emulsification ability of surfactant systems, and the results show that mixed surfactant systems can completely emulsify the crude oil into emulsions droplets even under low energy conditions. Meanwhile,the system exhibits good temperature and salt resistance. Finally, the best oil recovery of 25.45% is achieved for low permeability core by the mixed surfactant system with a total concentration of 0.3 wt%while the molar ratio of APGSHS:BS-18 is 4:6. The current study indicates that the anionic/zwitterionic mixed surfactant system can improve the oil flooding efficiency and is potential candidate for application in low permeability reservoirs.

关键词： Anionic/zwitterionic mixed surfactant system Emulsification Synergistic effect low permeability reservoir Enhanced oil recovery

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The coupling of dynamics and permeability in the hydrocarbon accumulation period controls the oil-bearing potential of low permeability reservoirs:a case study of the low permeability turbidite reservoirs in the middle part of the third member of Shahejie

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Petroleum Science 2016年第2期13卷 204-224页

作者： Tian Yang Ying-Chang Cao Yan-Zhong Wang Henrik Friis Beyene Girma Haile Ke-Lai Xi Hui-Na Zhang School of Geosciences China University of PetroleumQingdao 266580 Shandong China Laboratory for Marine Mineral Resources Qingdao National Laboratory for Marine Science and TechnologyQingdao 266071 China Department of Geoscience Aarhus University Hoegh-Guldbergs Gade 2 8000 Aarhus C Denmark Department of Geosciences University of OsloP.O. Box 1047 Blindern 0316 Oslo Norway

The relationships between permeability and dynamics in hydrocarbon accumulation determine oil- bearing potential （the potential oil charge） of low perme- ability reservoirs. The evolution of porosity and permeability of low permeability turbidite reservoirs of the middle part of the third member of the Shahejie Formation in the Dongying Sag has been investigated by detailed core descriptions, thin section analyses, fluid inclusion analyses, carbon and oxygen isotope analyses, mercury injection, porosity and permeability testing, and basin modeling. The cutoff values for the permeability of the reservoirs in the accumulation period were calculated after detailing the accumulation dynamics and reservoir pore structures, then the distribution pattern of the oil-bearing potential of reservoirs controlled by the matching relationship between dynamics and permeability during the accumulation period were summarized. On the basis of the observed diagenetic features and with regard to the paragenetic sequences, the reservoirs can be subdivided into four types of diagenetic facies. The reservoirs experienced two periods of hydro- carbon accumulation. In the early accumulation period, the reservoirs except for diagenetic facies A had middle to high permeability ranging from 10 × 10-3 gm2 to 4207 × 10-3 lain2. In the later accumulation period, the reservoirs except for diagenetic facies C had low permeability ranging from 0.015 × 10-3 gm2 to 62× 10-3 -3m2. In the early accumulation period, the fluid pressure increased by the hydrocarbon generation was 1.4-11.3 MPa with an average value of 5.1 MPa, and a surplus pressure of 1.8-12.6 MPa with an average value of 6.3 MPa. In the later accumulation period, the fluid pressure increased by the hydrocarbon generation process was 0.7-12.7 MPa with an average value of 5.36 MPa and a surplus pressure of 1.3-16.2 MPa with an average value of 6.5 MPa. Even though different types of reservoirs exist, all can form hydrocarbon accumulations i

关键词： reservoir porosity and permeabilityevolution Accumulation dynamics Cutoff-values ofpermeability in the accumulation period Oil-bearingpotential low permeability reservoir The third memberof the Shahejie Formation Dongying Sag

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Study on the Variation Rule of Produced Oil Components during CO_(2) Flooding in low permeability reservoirs

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Computer Modeling in Engineering & Sciences 2020年第6期123卷 1223-1246页

作者： Ganggang Hou Tongjing Liu Xinyu Yuan Jirui Hou Pengxiang Diwu Unconventional Petroleum Research Institute China University of PetroleumBeijingChina College of Science China University of PetroleumBeijingChina

CO_(2) flooding has been widely studied and applied to improve oil recovery from low permeability *** the experimental results and the oilfield production data indicate that produced oil components(POC)will vary during CO_(2) flooding in low permeability ***,the present researches fail to explain the variation reason and *** this study,the physical model of the POC variation during CO_(2) flooding in low permeability reservoir was established,and the variation reason and rule were *** verify the correctness of the physical model,the interaction rule of the oil-CO_(2) system was studied by related *** numerical model,including 34 components,was established based on the precise experiments matching,and simulated the POC variation during CO_(2) flooding in low permeability reservoir at different inter-well reservoir *** POC monitoring data of the CO_(2) flooding pilot test area in northeastern China were analyzed,and the POC variation rule during the oilfield production was *** research results indicated that the existence of the inter-well channeling-path and the permeability difference between matrix and channeling-path are the main reasons for the POC variation during CO_(2) flooding in low permeability *** POC variation rules are not the same at different inter-well reservoir *** the low permeability reservoirs with homogeneous inter-well reservoir,the variation of the light hydrocarbon content in POC increases initially followed by a decrease,while the variation of the heavy hydrocarbon content in POC is completely *** carbon number of the most abundant component in POC will gradually *** the low permeability reservoirs with the channeling-path existing in the inter-well reservoir,the variation rule of the light hydrocarbon content in POC is increase-decrease-increase-decrease,while the variation rule of the heavy hydrocarbon content in POC is co

关键词： low permeability reservoir CO_(2)flooding produced oil component inter-well reservoirs characteristic

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