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Development and preservation mechanism of deep and ultra-deep carbonate reservoirs

Science China Earth Sciences 2024年第11期67卷 3367-3385页

作者： Anjiang SHEN Anping HU Zhanfeng QIAO Jianfeng ZHENG Min SHE Liyin PAN Key Laboratory of carbonate Reservoir CNPCHangzhou 310023China State Energy Key Laboratory of carbonate Oil and Gas Hangzhou 310023China PetroChina Hangzhou Research Institute of Geology Hangzhou 310023China

Exploration practice has proved that deep and ultra-deep reservoirs consist of mainly matrix-porous dolomite reservoirs and fractured-vuggy karst reservoirs and still will be very important targets for future exploration, in which large oil and gas fields such as Anyue, Yuanba, Halahatang, Fuman and Shunbei have been discovered. This paper systematically summarizes three theoretical and technical achievements in studying deep and ultra-deep carbonate reservoirs in the past decade.(1) The micro-zone and multi-parameter experiment analysis technology featured by determining the “age, temperature, pressure and fluid properties” of carbonate reservoirs, together with experimental simulation of cross-tectonic-period pore formation and preservation featured by the “multi-stage, continuous, visualized and online detection technology”, providing useful tools for studying the pore formation and preservation mechanism of deep and ultra-deep carbonate rocks from the perspective of“forward” and “inversion”.(2) Deep and ultra-deep matrix-porous dolostone reservoirs are still controlled by sedimentary facies,among which reef(mound) and/or beach contribute most. The reservoir space is mainly composed of sedimentary primary pores and supergene dissolution pores and fractures, though some of reservoir spaces are formed by burial dissolution and they tend to develop and may locally concentrate following the pre-existing porous zone. In other words, burial dissolution vugs are inherited rather than newly formed. Early dolomite precipitation(or dolomitization) has a high potential to preserve early pores.(3) The development and preservation mechanism of fractured-vuggy karst limestone reservoirs in deep and ultra-deep realm was analyzed. Pene-contemporaneous dissolution and interlayer and buried-hill karstification control the development of early and late supergene fractured-vuggy reservoirs. Strike-slip faults superimposed with supergene karstification lead to the development of “fen

关键词： Deep and ultra-deep formation carbonate reservoirs Matrix-porous dolomite reservoir Fractured-vuggy karst reservoir Genersis and distribution of carbonate reservoirs

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Using a Modified GOI Index(Effective Grid Containing Oil Inclusions)to Indicate Oil Zones in carbonate reservoirs

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Acta Geologica Sinica(English Edition) 2015年第3期89卷 902-910页

作者： ZHANG Nai PAN Wenlong TIAN Long YU Xiaoqing JIANG Jing JIN Xu Research Institute of Petroleum Exploration and Development PetroChina School of Earth Science and Resources China University of Geosciences Department of Earth and Environmental Sciences University of Waterloo School of Energy Resources China University of Geosciences

The GOI（grains containing oil inclusions） index is used to distinguish oil zones,oil-water zones and water zones in sandstone oil ***,this method cannot be directly applied to carbonate rocks that may not have clear granular *** this paper we propose the Effective Grid Containing Oil Inclusions（EGOI） method for carbonate reservoirs.A microscopic view under10× ocular and 10 x objective is divided into 10×10 grids,each with an area of 0.0625 mm×0.0625 *** effective grid is defined as one that is cut（touched） by a stylolite,a healed fracture,a vein,or a pore-filling *** is defined as the number of effective grids containing oil inclusions divided by the total number of effective grids multiplied by 100%.Based on data from the Tarim Basin,the EGOI values indicative of the paleo-oil zones,oil-water zones,and water zones are 〉5%,1%-5%,and 〈1%,***,the oil zones in young reservoirs（charged in the Himalayan） generally have lower EGOI values,typically 3%-5%.

关键词： GOI EGOI ancient oil reservoirs late accumulation carbonate reservoirs

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A two-step method to apply Xu–Payne multi-porosity model to estimate pore type from seismic data for carbonate reservoirs

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Petroleum Science 2020年第3期17卷 615-627页

作者： Hong-Bing Li Jia-Jia Zhang Sheng-Juan Cai Hao-Jie Pan Research Institute of Petroleum Exploration and Development Petrochina Company LimitedBeijing 100083China School of Geosciences China University of Petroleum(East China)Qingdao 266580China

carbonate reservoirs exhibit strong heterogeneity in the distribution of pore types that can be quantitatively characterized by applying Xu–Payne multi-porosity ***,there are some prerequisites to this model the porosity and saturation need to be *** general,these application conditions are difficult to satisfy for seismic *** order to overcome this problem,we present a two-step method to estimate the porosity and saturation and pore type of carbonate reservoirs from seismic *** step one,the pore space of the carbonate reservoir is equivalent to a single-porosity system with an effective pore aspect ratio;then,a 3D rock-physics template(RPT)is established through the Gassmann’s equations and effective medium models;and then,the effective aspect ratio of pore,porosity and fluid saturation are simultaneously estimated from the seismic data based on 3D *** step two,the pore space of the carbonate reservoir is equivalent to a triple-porosity *** with the inverted porosity and saturation in the first step,the porosities of three pore types can be inverted from the seismic elastic *** application results indicate that our method can obtain accurate physical properties consistent with logging data and ensure the reliability of characterization of pore type.

关键词： carbonate reservoirs Pore type Physical properties Rock-physics modeling Rock-physics inversion

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Evaluation of sour gas-low salinity waterflooding in carbonate reservoirs-A numerical simulation approach

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Petroleum Research 2023年第2期8卷 131-150页

作者： Lawrence Opoku Boampong Roozbeh Rafati Amin Sharifi Haddad School of Engineering University of AberdeenFN371Fraser Noble BuildingSchool of EngineeringUniversity of AberdeenAB243UEUK

Although significant amount of H_(2)S(sour gas)rich natural gas is estimated globally,but not much attention has been given to the application of H_(2)S in the oil recovery *** studies on the use of H_(2)S in oil recovery processes showed that H_(2)S has the potential of improving the oil recovery,and it can be even more effective than using CO_(2) in some processes.H_(2)S can equally dissolve in the water,react with the reservoir rock to change its surface charge,porosity,and ***,previous in-vestigations on H_(2)S oil recovery attributed the improved oil recoveries to the higher miscibility of H_(2)S in the oil,and the reduction in the oil ***,there is limited understanding on the H_(2)S-oil-brine-rock geochemical interactions,and how they impact the oil recovery *** study aims to investigate the interactions between H_(2)S,oil,and carbonate formations,and to assess how the combi-nation of H_(2)S and low salinity water can impact the wettability and porosity of the reservoirs.A triple layer surface complexation model was used to understand the influence of key parameters(e.g.,pressure,brine salinity,and composition)on the H_(2)S-brine-oil-rock ***,the effects of mineral content of the carbonate rock on H_(2)S interactions were ***,the results of the H_(2)S-oil-brine-rock interactions were compared with a study where CO_(2) was used as the injected *** of the study showed that the seawater and its diluted forms yielded identicalζ-potential values of about 3.31 mV at a pH of *** indicates that at very low pH condition,pH controls the ζ-potential of the oil-brine interface regardless of the brine's ionic *** study further demonstrated that the presence of other minerals in the carbonate rock greatly reduced the calcite *** instance,the calcite dissolution was reduced by 4.5%when anhydrite mineral was present in the carbonate *** from the s

关键词： Low salinity water flooding Zeta potential Wettability alteration carbonate reservoirs Carbon dioxide storage Sour gas injection

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Role of the injected water salinity and ion concentrations on the oil recovery in carbonate reservoirs

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Petroleum Research 2022年第3期7卷 394-400页

作者： M.Fouad Snosy Mahmoud Abu El Ela Ahmed El-Banbi Helmy Sayyouh Petroleum Engineer General Petroleum CompanyEgypt Professor of Petroleum Engineering Cairo UniversityEgypt Professor of Petroleum Engineering The American University in CairoEgypt

Low salinity water flooding(LSWF)was initially considered using water with a low concentration of dissolved salts and was later extended to include modifying the ionic content of injected *** work investigates the effects of changing water salinity and composition along with the concentration of sulfate and iodide ions on oil recovery in carbonate reservoirs during the tertiary recovery *** experimental study was carried out using crude oil of 29°API,8 core samples extracted from the Eocene carbonate reservoir(Egypt),and 6 different water *** results showed additional oil recovery up to 5%of the original oil in place(OOIP)in the tertiary recovery stage with changing water salinity and water *** of high salinity(HS)and low salinity(LS)brines with high sulfate concentrations increased the incremental oil recovery by a value ranging from 1.7 to 3.8%of the *** the contrary,injection of HS and LS brines with low sulfate concentrations showed insignificant incremental oil recovery(less than 1%of the OOIP).Furthermore,injection of water with potassium iodide(KI)after injection of water with high sulfate brines showed additional oil recovery of about 1.7%of the *** the other hand,injection of water with KI after injection of water with low sulfate concentration showed insignificant incremental oil recovery(less than 0.4%of the OOIP).The concentration of sulfate in the injected water appeared to be key parameter to achieve effective waterflooding(WF)projects in carbonate ***,the results revealed that the multi-component ion exchange(MIE)mechanism seems to be the primary recovery mechanism for LSWF in carbonate *** results and conclusions of this study can be used to develop guidelines for designing waterflooding projects in carbonate reservoirs with optimum salinity.

关键词： Low salinity waterflooding carbonate reservoirs Waterflooding LSWF

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Effects of Formation Mineral Compositions on the Performance of High- & Low-Salinity Brine Injection in carbonate reservoirs

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World Journal of Engineering and Technology 2024年第4期12卷 1008-1023页

作者： Abdulrazag Y. Zekri Mamdouh Taha Ghannam Musaab Ibrahim Magzoub Chemical and Petroleum Engineering Department UAE University Al Ain UAE

Low-salinity flooding has been extensively investigated. However, the effects of several variables, such as mineralogical composition, have been neglected. In this regard, the main objective here was to optimize low-salinity water flooding of reservoirs with a wide range of rock mineralogy. Five different brines were determined in reservoirs with different mineral compositions. The mineral composition consisted of limestone and dolomite and the mineralogy varied between 0 and 100% limestone content. The results indicated that the optimum mineralogical system consists of 50% limestone and 50% dolomite flooded with 100% diluted formation brine. Additionally, reservoir mineral composition plays a significant role in the performance of low-salinity water flooding. The findings here will improve our understanding of rock composition effects on the performance of low-salinity water flooding and provide the industry with data that can scientifically improve process optimization.

关键词： Water Flooding Low Salinity carbonate reservoirs Rock Mineralogy Limestone

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Geochemical Characteristics and Migration Pathways of Ordovician carbonate Oil reservoirs in the Tuoputai Area,Tarim Basin,Northwestern China

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Acta Geologica Sinica(English Edition) 2021年第4期95卷 1295-1309页

作者： LIU Hua WANG Shen CHENG Bin CAO Zicheng JIANG Ziyue Key Laboratory of Deep Oil and Gas School of GeosciencesChina University of Petroleum(East China)QingdaoShandong 266580China Laboratory for Marine Mineral Resources Qingdao National Laboratory for Marine Science and TechnologyQingdaoShandong 266071China Northwest Oilfield Branch Company Ltd. SINOPECUrumqi 830011China

Exploration potential is huge and the oil resources are rich in the Ordovician reservoirs of the Tarim ***,the mechanism of hydrocarbon accumulation is complex and not yet fully *** the Tuoputai area,the hydrocarbon migration pathways and characteristics of deep hydrocarbon accumulation are revealed through analyses of the physical data of rich oil and gas,the geochemical parameters of oil,and fluid *** results show that the Ordovician oils in the Tuoputai area have the same geochemical characteristics as the mixed oil from the Lower Cambrian source rock and the Middle–Upper Ordovician source *** Ordovician reservoirs have been charged three times:in the late Caledonian,late Hercynian,and Himalayan *** charging occurred in the Hercynian stage,in particular,as it is the main filling period of *** north-northeast(NNE)-trending TP12 CX major fault,active in in these times and is dominant migration channel of hydrocarbon,but there is segmentation affected by the difference of *** maturity is higher in the south than in the north and is abnormally high near the major *** related to migration indicate that oil migrated northeastward along the NNE-trending TP12 CX major fault and adjusted laterally along the secondary faults and weathering crust,forming the present characteristics of oil and gas distribution.

关键词： carbonate reservoirs oil geochemical characteristics oil migration pathways deep oil and gas Tuoputai area Tarim Basin

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Stochastic seismic inversion and Bayesian facies classification applied to porosity modeling and igneous rock identification

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Petroleum Science 2024年第2期21卷 918-935页

作者： Fábio Júnior Damasceno Fernandes Leonardo Teixeira Antonio Fernando Menezes Freire Wagner Moreira Lupinacci Exploratory Interpretation and Reservoir Characterization Group(GIECAR) Department of Geology and GeophysicsFederal Fluminense UniversityNiter oiRJ24210-346Brazil Petrobras Rio de JaneiroRJ20231-030Brazil National Institute of Science and Technology of Petroleum Geophysics(INCT-GP/CNPQ) Niter oiRJ24210-346Brazil

We apply stochastic seismic inversion and Bayesian facies classification for porosity modeling and igneous rock identification in the presalt interval of the Santos Basin. This integration of seismic and well-derived information enhances reservoir characterization. Stochastic inversion and Bayesian classification are powerful tools because they permit addressing the uncertainties in the model. We used the ES-MDA algorithm to achieve the realizations equivalent to the percentiles P10, P50, and P90 of acoustic impedance, a novel method for acoustic inversion in presalt. The facies were divided into five: reservoir 1,reservoir 2, tight carbonates, clayey rocks, and igneous rocks. To deal with the overlaps in acoustic impedance values of facies, we included geological information using a priori probability, indicating that structural highs are reservoir-dominated. To illustrate our approach, we conducted porosity modeling using facies-related rock-physics models for rock-physics inversion in an area with a well drilled in a coquina bank and evaluated the thickness and extension of an igneous intrusion near the carbonate-salt interface. The modeled porosity and the classified seismic facies are in good agreement with the ones observed in the wells. Notably, the coquinas bank presents an improvement in the porosity towards the top. The a priori probability model was crucial for limiting the clayey rocks to the structural lows. In Well B, the hit rate of the igneous rock in the three scenarios is higher than 60%, showing an excellent thickness-prediction capability.

关键词： Stochastic inversion Bayesian classification Porosity modeling carbonate reservoirs Igneous rocks

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Main progress and problems in research on Ordovician hydrocarbon accumulation in the Tarim Basin

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Petroleum Science 2010年第2期7卷 147-163页

作者： Pang Xiongqi Tian Jun Pang Hong Xiang Caifu Jiang Zhenxue Li Sumei Basin and Reservoir Research Center School of Natural Resources and Information Technology China University ofPetroleum Beijing 102249 China State Key Laboratory of Petroleum Resources and Prospecting China University of Petroleum Beijing 102249 China PetroChina Tarim Oilfield Company Korla Xinjiang 841000 China

The Tarim Basin is the largest petroliferous basin in the northwest of China, and is composed of a Paleozoic marine craton basin and a Meso-Cenozoic continental foreland basin. It is of great significance in exploration of Ordovician. In over 50 years of exploration, oil and gas totaling over 1.6 billion tonnes oil-equivalent has been discovered in the Ordovician carbonate formation. The accumulation mechanisms and distribution rules are quite complicated because of the burial depth more than 3,500 m, multi-source, and multi-stage accumulation, adjustment, reconstruction and re-enrichment in Ordovician. In this paper, we summarized four major advances in the hydrocarbon accumulation mechanisms of Ordovician carbonate reservoirs. First, oil came from Cambrian and Ordovician source rocks separately and as a mixture, while natural gas was mainly cracked gas generated from the Cambrian-Lower Ordovician crude oil. Second, most hydrocarbon migrated along unconformities and faults, with different directions in different regions. Third, hydrocarbon migration and accumulation had four periods： Caledonian, early Hercynian, late Hercynian and Himalayan, and the latter two were the most important for oil and gas exploration. Fourth, hydrocarbon accumulation and evolution can be generally divided into four stages： Caledonian （the period of hydrocarbon accumulation）, early Hercynian （the period of destruction）, late Hercynian （the period of hydrocarbon reconstruction and re-accumulation）, and Himalayan （the period of hydrocarbon adjustment and re-accumulation）. Source rocks （S）, combinations of reservoir-seal （C）, paleo-uplifts （M）, structure balance belt （B） matched in the same time （T） control the hydrocarbon accumulation and distribution in the Ordovician formations. Reservoir adjustment and reconstruction can be classified into two modes of physical adjustment and variation of chemical compositions and five mechanisms. These mechanisms are occurrence displacement, biodegradat

关键词： Tarim Basin carbonate reservoirs oil and gas exploration of the Ordovician hydrocarbon accumulation mechanism hydrocarbon enrichment rule

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Conventional diverting techniques and novel fibr-assisted selfdiverting system in carbonate reservoir acidizing with successful case studies

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Petroleum Research 2021年第3期6卷 247-256页

作者： Reza Abdollahi Hamid Esfandyari Mahdi Nadri Pari Afshin Davarpanah EOR Research Department Research Institute of Petroleum IndustryTehranIran Department of Petroleum Engineering Abadan Faculty of Petroleum EngineeringPetroleum University of Technology(PUT)AbadanIran Department of Mathematics Aberystwyth UniversityAberystwyth SY233BZUnited Kingdom

Conventional diverting techniques may not be useful,and the use of the advanced and well-documented diverting technique is needed to overcome the complexity and heterogeneity of carbonate ***,there have been a lot of materials and techniques utilized for acid *** paper aimed to consider various utilization of fiber-assisted self as the diverting system in acidifying carbonate res*** of the main reasons for its ability to overcome uncertainty is that the fiber itself is an inherent property,allowing for an automatic diversion adjustment *** a media with infinite permeability,such as a perforation tunnel or natural fracture,is filled and bridged with a material of finite permeability such as degradable fiber,this creates a temporary skin to injectivity in that *** is a powerful concept,as it is a way,despite uncertainty from a lack of logging data or uncertainty in the data itself,of dampening the reservoir’s natural permeability *** does not rely on petrophysical certainty to design a successful treatment.

关键词： Acidizing carbonate reservoirs Diversion techniques Fiber-assisted self-diverting system Fracture Wormhole

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