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Synchronous injection-production energy replenishment for a horizontal well in an ultra-low permeability sandstone reservoir: A case study of Changqing oilfield in Ordos Basin, NW China

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Petroleum Exploration and Development 2020年第4期47卷 827-835页

作者： WANG Jing LIU Jungang LI Zhaoguo LI Hongchang ZHANG Jiaosheng LI Wenqing ZHANG Yuanli PING Yi YANG Huanying WANG Ping Exploration and Development Research Institute of PetroChina Changqing Oilfield Company Xi’an 710018China National Engineering Laboratory for Exploration and Development of Low-Permeability Oil&Gas Fields Xi’an 710018China

It is difficult to build an effective water flooding displacement pressure system in the middle section of a horizontal well in an ultra-low permeability sandstone reservoir.To solve this problem,this study proposes to use packers,sealing cannula and other tools in the same horizontal well to inject water in some fractures and produce oil from other fractures.This new energy supplement method forms a segmental synchronous injection-production system in a horizontal well.The method can reduce the distance between the injection end and the production end,and quickly establish an effective displacement system.Changing the displacement between wells to displacement between horizontal well sections,and point water flooding to linear uniform water flooding,the method can enhance water sweeping volume and shorten waterflooding response period.The research shows that:(1)In the synchronous injection and production of horizontal well in an ultra-low-permeability sandstone reservoir,the water injection section should select the section where the natural fractures and artificial fractures are in the same direction or the section with no natural fractures,and the space between two sections should be 60?80 m.(2)In addition to controlling injection pressure,periodic water injection can be taken to reduce the risk of re-opening and growth of natural fractures or formation fracture caused by the gradual increase of water injection pressure with water injection going on.(3)Field tests have verified that this method can effectively improve the output of single well and achieve good economic benefits,so it can be widely used in the development of ultra-low permeability sandstone reservoirs.

关键词： ultra-low permeability reservoir sandstone reservoir horizontal well staged fracturing synchronous injection-production intersegment displacement development effect

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Application of thermotolerant petroleum microbes at reservoir conditions for enhanced oil recovery

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Petroleum 2023年第2期9卷 223-236页

作者： Emmanuel E.Okoro Ewarezi A.Efajemue Samuel E.Sanni Oluwasanmi A.Olabode Oyinkepreye D.Orodu Temiloluwa Ojo Petroleum Engineering Department University of Port HarcourtChobaNigeria Petroleum Engineering Department Covenant UniversityOtaNigeria Chemical Engineering Department Covenant UniversityOtaNigeria

Primary oil recovery is the first stage of hydrocarbon production in which a reservoir uses its natural energy to force hydrocarbon to its wellbore.Secondary oil recovery comes to play when hydrocarbons can no longer be further produced by natural means.The purpose of secondary recovery is to maintain reservoir pressure so as to displace hydrocarbons toward the wellbore.Both primary and secondary recovery processes cannot displace more than 50%of the available hydrocarbons in a reservoir.The remaining hydrocarbons are further recovered through Tertiary/Enhanced Oil Recovery techniques.According to literature,microbial enhanced oil recovery has been identified as a tertiary method used to improve the efficiency of hydrocarbon production from reservoirs.Microbial enhanced oil recovery is a feasible reservoir technology,which has not been widely used in the oil and gas industry owing to the attainment of the requisite reservoir conditions such as temperature within which microbes can thrive.Literature has shown that thermotolerant microbes can withstand optimum temperatures of 50e90℃,while deep and ultra-deep hydrocarbon reservoir temperatures are often above 100℃.This study identifies some isolated thermotolerant microbes from a sandstone reservoir that can withstand temperatures as high as 110℃via conventional methods and molecular analysis.The identified thermotolerant petroleum microbes:Bacillus amyloliquefaciens(A)and Bacillus nealsonii(B)were used to enhance oil recovery from a reservoir.The results showed that the microbial species A and B at a confined pressure of 3.0 MPa and temperature of 27℃,gave 46.4%and 48.6%oil recoveries,respectively,which is comparably higher than the value(26.9%)obtained for the water flooded samples.At temperatures of 80,90,100,110 and 120℃,the oil recovery results show that the recovery factor(55.2%e64.1%)of species B were higher compared to the range(46.7e57.5%)recorded for species A.At the onset of the core flooding experiments,there was an initial increment in oil recovery fact

关键词： Microbial enhanced oil recovery Thermotolerant petroleum microbes Recovery factor Microbe isolation/identification sandstone reservoir

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Physical properties of sandstone reservoirs: Implication for fluid mobility

Energy Geoscience

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Energy Geoscience 2022年第4期3卷 349-359页

作者： Richardson M.Abraham-A Fabio Taioli Anthony I.Nzekwu Institute of Energy and Environment University of Sao Paulo(IEE-USP)Sao PaloBrazil Department of Applied Geophysics Federal University of TechnologyAkure(FUTA)Ondo StateNigeria

Core samples representing depths of hydrocarbon-bearing zones are not readily accessible for reservoir evaluations.On the other hand,wireline logs with incorporated seismic data,which can be archived over a more extended period while retaining their original forms,are typically more available for research purposes.Therefore,the study relies on wireline logs with seismic data to predict the reservoirs'fluid mobility by evaluating the hydraulic(flow)units,reservoir depths,fluid saturations,and geothermal gradients.It also indicates the associated water cut(C_(w))within Ritchie oil and gas field,Niger Delta considering a three-phase(oil-gas-water-bearing)reservoir(R_(A))and an oil-saturated reservoir(R_(B))delineated across three wells(R_(W1),R_(W2) and R_(W3)).Research activities combining the presented factors to achieve the stated objectives are not quite common within the study location.It shows lower,average and upper limits of the flow unit factors and irreducible water saturation(S_(wirr))within the reservoirs.The study shows the relationship between hydraulic units/fluid saturations and fluid mobility/associated C_(w) within the sandstone reservoirs.It maximises porosity(Ф)for the theoretical flow units'prediction during qualitative and quantitative estimation based on the adopted expressions.Therefore,the study reveals that water saturation(S_(w))and hydrocarbon/water ratios substantially control C_(w),and other contributing factors include thermal gradients and S_(wirr).The flow unit factors are also significant and will encourage fluid mobility.The evaluated reservoirs(R_(A) and R_(B))are below 10400 ft(3170 m)across wells R_(W1),R_(W2) and R_(W3) within the Agbada Formation of a geothermal gradient up to 2.7℃/100 m;therefore,they have good thermal conditions to enhance hydrocarbon mobility and increase S wirr.Hence,the reservoir should feature significant hydrocarbon extraction via primary recovery.The average water cut(C_(w-avg).)(12.3%)estimated for reservoir R_(A) is within the acceptable range;theref

关键词： Water cut Thermal gradient Fluid saturations Hydrocarbon mobility sandstone reservoir reservoir quality Agbada Formation Niger Delta

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The Rock Physical Phase Partition Method of Multilayer sandstone reservoir Based on Fuzzy Inference Networks

The Rock Physical Phase Partition Method of Multilayer Sands...

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2011 International Conference on Computer Science and Information Technology(ICCSIT 2011)

作者： PAN JunHui Wang Hui Department of Computer and Information Technology NorthEast Petroleum University Daqing

ISBN: (纸本)9781510811249;1510811249

A kind of discrimination method based on weighted fuzzy inference networks is put forward in this paper according to the rock physical phase division problem of heterogeneous multilayer sandstone reservoir. In this method, the fuzziness of rock physical phase classification and meeting character of characteristic parameters are fully considered, and the cumulated expert experience in research are combined with the quantitative indexes which reflect the rock physical phase change. The rock physical phase classification types and deviding indexes are defined by the core analysis data of coring well and explaining results of expert, then the classification standard pattern library of rock physical phase is established. The rock physical appearance discrimination model of heterogeneous multilayer sandstone reservoir based on weighted fuzzy inference networks is established by adopting the adaptive learning mechanism. The experimental results demonstrate that the method has good application effect by processing the actual data from Daqing oilfield.

关键词： physical phase heterogeneous sandstone reservoir fuzzy inference network pattern recognition

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Cross-flow analysis of injection wells in a multilayered reservoir

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Petroleum 2016年第3期2卷 273-281页

作者： Mohammadreza Jalali Jean-Michel Embry Francesco Sanfilippo Frederic J.Santarelli Maurice B.Dusseault Geological Institute ETH ZurichZurichSwitzerland Baker Hughes AberdeenUnited Kingdom Geomec Environmental Management AS StavangerNorway Earth&Environmental Sciences Department University of WaterlooWaterlooONCanada

During fluid injection into a multilayered reservoir,a different pressure gradient is generated across the face of each permeable layer.This pressure gradient generates driving forces in the wellbore during well shut-in that causes the injected fluid moves from higher pressure layers to lower pressure layers,a phenomenon known as interwell cross-flow.Cross-flow behavior depends on the initial pressure in the permeable layers and may be referred to as natural cross-flow(identical or natural initial pressures)and forced cross-flow(different initial pressures because of exploitation).Cross-flow may induce sand production and liquefaction in the higher pressure layers as well as formation damage,filter cake build-up and permeability reduction in the lower pressure layers.Thus,understanding cross-flow during well shut-in is important from a production and reservoir engineering perspective,particularly in unconsolidated or poorly consolidated sandstone reservoirs.Natural and forced cross-flow is modeled for some injection wells in an oil reservoir located at North Sea.The solution uses a transient implicit finite difference approach for multiple sand layers with different permeabilities separated by impermeable shale layers.Natural and forced cross-flow rates for each reservoir layer during shut-in are calculated and compared with different production logging tool(PLT)measurements.It appears that forced cross-flow is usually more prolonged and subject to a higher flow rate when compared with natural cross-flow,and is thus worthy of more detailed analysis.

关键词： Cross-flow Multilayered sandstone reservoir Sand production Skin factor

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Depositional and Diagenetic Controls on sandstone reservoirs with Low Porosity and Low Permeability in the Eastern Sulige Gas Field, China

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Acta Geologica Sinica(English Edition) 2014年第5期88卷 1513-1534页

作者： YANG Renchao FAN Aiping A.J.van LOON HAN Zuozhen WANG Xiuping Shandong Provincial Key Laboratory of Depositional Mineralization & Sedimentary Minerals College of Earth Science and Engineering Shandong University of Science and Technology Institute of Geology Adam Mickiewicz UniversityMaków Polnych 16 61-606 Poznan Poland

In order to determine the genesis and the factors that control the low-porosity and low- permeability sandstone reservoirs in the eastern Sulige Gas Field in the Ordos Basin, systematic studies on the sedimentary facies and diagenesis were conducted by means of analysis of cores, thin sections, fluid inclusions, X-ray diffraction, cathode luminescence and scanning electron microscope. It was found that the sand bodies of the major gas reservoirs in the Shan1 section （P1S1） and the He8 section （P2H8） were formed during the Permian as sedimentary facies such as braided-channel bars, braided-river channels and point bars of a meandering river. Four types of diagenetic facies developed subsequently： in order from the best to the poorest properties these are type A （weak compaction, early calcite cement-chlorite film facies）, type B （moderate compaction, quartz overgrowth-feldspar corrosion-kaolinite filling facies）, type C （strong compaction, late calcite cement-quartz corrosion facies） and type D （matrix filling and strong compaction facies）. This diagenesis is undoubtedly the main reason for the poor reservoir properties of sandstone reservoirs, but the sedimentary facies are the underlying factors that greatly affect the diagenesis and thus the reservoir performance. Favorable diagenetic facies developed mainly in relatively small lithofacies such as braided-river channels, channel bars and point bars. The vertical distribution of the physical properties and the diagenetic facies of the reservoirs are related to the stratigraphic succession. Most of the sandstones between mudstones and thin beds of sandstone are unfavorable diagenetic facies. Analyses indicate that siliceous cementation can hardly be stopped by hydrocarbon filling. Authigenic chlorite could hardly protect the primary porosity. It not only occupies pore space, but also blocks pathways through sandstone reservoirs, so that it has significant influence on the permeability. Authigenic chlorite cannot be used as a marker for a specific sedimentary faci

关键词： Ordos Basin Sulige Gas Field sandstone reservoir sedimentary facies diagenesis,diagenetic facies

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Detrital K-feldspar^(40)Ar/^(39)Ar Ages:Source Constraints of the Lower Miocene sandstones in the Pearl River Mouth Basin,South China Sea

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Acta Geologica Sinica(English Edition) 2012年第2期86卷 383-392页

作者： LIU Zaisheng SHI Hesheng ZHU Junzhang QIU Huaning ZHANG Zhilin YUN Jianbing CNOOC China Limited Shenzhen Shenzhen 518067China State Key Laboratory of Isotopic Geochemistry Guangzhou Institute of GeochemistryChinese Academy of SciencesGuangzhou 510640China Hailaer Petroleum Exploration and Development Headquarters PetroChina Daqing Oilfield Company Ltd.Hailar 021000China

The South China Sea began to outspread in the Oligocene. A great quantity of terraneous detritus was deposited in the northern continental shelf of the sea, mostly in Pearl River Mouth Basin, which constituted the main paleo-Pearl River Delta. The delta developed for a long geological time and formed a superimposed area. Almost all the oil and gas fields of detrital rock reservoir distribute in this delta. Thirty-three oil sandstone core samples in the Zhujiang Formation, lower Miocene （23-16 Ma）, were collected from nine wells. The illite samples with detrital K feldspar （Kfs） separated from these sandstone cores in four sub-structural belts were analysed by the high-precision 40Ar/39Ar laser stepwise heating technique. All 33 illite 40Ar/39Ar data consistently yielded gradually rising age spectra at the low-temperature steps until reaching age plateaus at mid-high temperature steps. The youngest ages corresponding to the beginning steps were interpreted as the hydrocarbon accumulation ages and the plateau ages in mid-high temperature steps as the contributions of the detrital feldspar representing the ages of the granitic parent rocks in the provenances. The ages of the detrital feldspar from the Zhujiang Formation in the four sub-structural belts were different：（1） the late Cretaceous ages in the Lufeng 13 fault structural belt; （2） the late Cretaceous and early Cretaceous-Jurassic ages in the Huizhou 21 buried hill-fault belt; （3） the Jurassic and Triassic ages in the Xijiang 24 buried hill-fault belt; and （4） the early Cretaceous - late Jurassic ages in the Panyu 4 oil area. These detrital feldspar 4~Ar/39Ar ages become younger and younger from west to east, corresponding to the age distribution of the granites in the adjacent Guangdong Province, Southern China.

关键词： Illite detrital K feldspar 40Ar/39Ar dating parent rock sandstone reservoir Pearl River Mouth Basin

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Evaluation and prevention of formation damage in offshore sandstone reservoirs in China

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Petroleum Science 2008年第4期5卷 340-347页

作者： Yang Shenglai Sheng Zhichao Liu Wenhui Song Zhixue Wu Ming Zhang Jianwei Key Laboratory of Petroleum Engineering Ministry of Education China University of Petroleum Beijing 102249 China Bohai Oil Research Institute CNOOC Tianjin 230045 China

Reduction in water injectivity would be harmful to the waterflood development of offshore sandstone oil reservoirs. In this paper the magnitude of formation damage during water injection was evaluated by analyzing the performance of water injection in the Bohai offshore oilfield, China. Two parameters, permeability reduction and rate of wellhead pressure rise, were proposed to evaluate the formation damage around injection wells. The pressure performance curve could be divided into three stages with different characteristics. Analysis of field data shows that formation damage caused by water injection was severe in some wells in the Bohai offshore oilfield, China. In the laboratory, the content of clay minerals in reservoir rock was analyzed and sensitivity tests （including sensitivity to water, ftow rate, alkali, salt and acid） were also conducted. Experimental results show that the reservoir had a strong to medium sensitivity to water （i.e. clay swelling） and a strong to medium sensitivity to flow rate, which may cause formation damage. For formation damage prevention, three injection schemes of clay stabilizer （CS） were studied, i.e. continuous injection of low concentration CS （CI）, slug injection of high concentration CS （SI）, and slug injection of high concentration CS followed by continuous injection of low concentration CS （SI-CI）. Core flooding experiments show that SI-CI is an effective scheme to prevent formation damage and is recommended for the sandstone oil reservoirs in the Bohai offshore oilfield during water injection.

关键词： sandstone reservoir formation damage water injection clay stabilizer

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Enhanced oil recovery of low salinity water flooding in sandstone and the role of clay

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Petroleum Exploration and Development 2018年第5期45卷 927-931页

作者： Al-SAEDI Hasan N FLORI Ralph E Missouri University of Science and Technology

sandstone core and free-clay sandstone core were prepared in chromatography columns, and core flooding experiments were performed to determine the EOR mechanisms of low salinity（LS） water flooding and analyze the effect of clay on recovery factor. First, brine with a high salinity（HS） of 100 000 mg/L was injected to simulate formation water. Then, LS water of 1 000 mg/L was then injected at different temperatures. Concentrations of Ca;and CH;COO;and pH of the fluid flowing out of the chromatography column were recorded. The results showed that during flooding the free-clay core with LS water, the carboxylic acid detached from the sand, as great as that of the clay-containing cores. It showed a noteworthy desorption of Ca;from the free-clay core surface, which indicated that LS water flooding resulted in a high recovery in sandstone without clay. Compared with HS water flooding, in the LS water flooding, the p H of produced fluid increased significantly; also, as the temperature increased, the pH and Ca;concentration of the produced fluid decreased; and the hydrophilic property of the sandstone was stronger. The results of oil recovery tests using the same columns were in line with the chemical analyses. The oil recovery from the free-clay columns was as great as from the column clay-containing column. The results of wettability measurements supported our theory.

关键词： sandstone reservoir low salinity water flooding enhanced oil recovery water-rock reaction wettability alteration clay

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Genesis Types and Diagenesis Compaction Mechanisms of sandstone Rreservoirs in Dynamic Environments in Oil/Gas Basins in China

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Petroleum Science 2006年第3期3卷 23-31页

作者： Shou Jianfeng Si Chunsong Wang Xin Hangzhou Institute of Petroleum Geology CNPC Hangzhou Zhejiang 310023 China

The diversity of sandstone diagenesis mechanisms caused by the complex geological conditions of oil/gas basins in China could hardly be reasonably explained by the traditional concept of burial diagenesis. Three genesis types of thermal diagenesis, tectonic diagenesis and fluid diagenesis are presented on the basis of the dynamic environment of the oil/gas basins and.the controlling factors and mechanisms of sandstone diagenesis. Thermal diagenesis of sandstone reservoirs is related not only to the effect of formation temperature on diagenesis, but also to the significant changes in diagenesis caused by geothermal gradients. The concept of thermal compaction is presented. Thermal compaction becomes weaker with increasing depth and becomes stronger at a higher geothermal gradient. At the same formation temperature, the sandstone porosity in the region with a lower geothermal gradient is e^0.077＋0.0042T times higher than that in the region with a higher geothermal gradient. Both sudden and gradual changes are observed in diagenetic evolution caused by structural deformation. Average sandstone compaction increased by 0.1051% for every 1.0MPa increase of lateral tectonic compressional stress, while late tectonic napping helped to preserve a higher porosity of underlying sandstone reservoir. Fluid diagenesis is a general phenomenon. The compaction caused by fluid properties is significant. The coarser the grain size, the stronger the fluid effect on compaction. The greater the burial depth, the weaker the fluid effect on compaction for the specific reservoir lithology and the greater the difference in the fluid effects on compaction between different grain sizes.

关键词： Oil/gas basins in China sandstone reservoir genesis types diagenesis compaction mechanism

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