RU2012113376A - METHOD FOR DETERMINING WATERFILL RATE AND COMPOSITION OF OIL WELL - Google Patents

METHOD FOR DETERMINING WATERFILL RATE AND COMPOSITION OF OIL WELL Download PDF

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RU2012113376A
RU2012113376A RU2012113376/03A RU2012113376A RU2012113376A RU 2012113376 A RU2012113376 A RU 2012113376A RU 2012113376/03 A RU2012113376/03 A RU 2012113376/03A RU 2012113376 A RU2012113376 A RU 2012113376A RU 2012113376 A RU2012113376 A RU 2012113376A
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coefficient
oil
water
saturation
permeability
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RU2012113376/03A
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RU2505676C2 (en
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Василий Сергеевич Белохин
Георгий Александрович Калмыков
Наталия Леонидовна Кашина
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Общество с ограниченной ответственностью ООО "Сплит"
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Priority to PCT/RU2012/000329 priority patent/WO2013151455A1/en
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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N23/00—Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups G01N3/00 – G01N17/00, G01N21/00 or G01N22/00
    • G01N23/005—Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups G01N3/00 – G01N17/00, G01N21/00 or G01N22/00 by using neutrons
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N33/00—Investigating or analysing materials by specific methods not covered by groups G01N1/00 - G01N31/00
    • G01N33/24—Earth materials
    • G01N33/246—Earth materials for water content
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N15/00—Investigating characteristics of particles; Investigating permeability, pore-volume, or surface-area of porous materials
    • G01N15/08—Investigating permeability, pore-volume, or surface area of porous materials
    • G01N2015/0846—Investigating permeability, pore-volume, or surface area of porous materials by use of radiation, e.g. transmitted or reflected light
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N2223/00—Investigating materials by wave or particle radiation
    • G01N2223/60—Specific applications or type of materials
    • G01N2223/616—Specific applications or type of materials earth materials

Abstract

Способ определения коэффициента обводненности и состава притока нефтяной скважины, включающий проведение геофизических исследований скважины (ГИС) с использованием импульсного нейтрон-гамма спектрометрического каротажа, определение компонентного состава пород, включая пористость и коэффициент текущего нефтенасыщения (К), отличающийся тем, что предварительно подготавливают коллекцию образцов керна из коллекторов, вскрытых опорными скважинами, по результатам исследования которой, определяют: текущую водонасыщенность (К), коэффициенты относительной фазовой проницаемости по нефти и по воде (К'К'), экспоненциальные значения относительной водо- и нефтепроницаемости (nn), коэффициент глинистости (К), коэффициент пористости (К), петрофизические параметры (а, b) связи коэффициента остаточной водонасыщенности и отношения объемной глинистости к пористости, коэффициент остаточной нефтенасыщенность (К), далее рассчитывают коэффициент остаточного водонасыщения К=а·(К/К)+b, после чего вычисляют коэффициент обводненности притока (К) по следующей формуле,где К- коэффициент текущего нефтенасыщения, K- коэффициент остаточного водонасыщения, К- коэффициент остаточной нефтенасыщености, К'- коэффициент относительной фазовой проницаемости по нефти, К'- коэффициент относительной фазовой проницаемости по воде, n- экспоненциальное значение относительной водопроницаемости, n- экспоненциальное значение относительной нефтепроницаемости µ- коэффициент динамической вязкости нефти, µ- коэффициент динамической вязкости воды, далее по полученному коэффициенту обводненности проводят оценку ожидаемого состава притока.A method for determining the water cut coefficient and composition of an oil well inflow, including conducting geophysical well surveys (GIS) using pulsed neutron-gamma spectrometric logging, determining the component composition of rocks, including porosity and current oil saturation coefficient (K), characterized in that a sample collection is preliminarily prepared core from reservoirs uncovered by reference wells, according to the results of the study of which, determine: current water saturation (K), coefficient you are the relative phase permeability of oil and water (K'K '), the exponential values of the relative water and oil permeability (nn), the clay coefficient (K), the porosity coefficient (K), the petrophysical parameters (a, b) of the relationship between the residual water saturation coefficient and the ratio of volumetric clay to porosity, the coefficient of residual oil saturation (K), then calculate the coefficient of residual water saturation K = a · (K / K) + b, and then calculate the coefficient of water cut in the inflow (K) according to the following formula, where K is the coefficient of current n oil saturation, K is the coefficient of residual water saturation, K is the coefficient of residual oil saturation, K'is the coefficient of relative phase permeability to oil, K'is the coefficient of relative phase permeability to water, n is the exponential value of relative water permeability, n is the exponential value of relative oil permeability μ is the coefficient dynamic viscosity of oil, µ is the coefficient of dynamic viscosity of water, then, according to the obtained water cut coefficient, the expected composition of the inflow is estimated.

Claims (1)

Способ определения коэффициента обводненности и состава притока нефтяной скважины, включающий проведение геофизических исследований скважины (ГИС) с использованием импульсного нейтрон-гамма спектрометрического каротажа, определение компонентного состава пород, включая пористость и коэффициент текущего нефтенасыщения (Кн), отличающийся тем, что предварительно подготавливают коллекцию образцов керна из коллекторов, вскрытых опорными скважинами, по результатам исследования которой, определяют: текущую водонасыщенность (Кв), коэффициенты относительной фазовой проницаемости по нефти и по воде (К'прн К'прв), экспоненциальные значения относительной водо- и нефтепроницаемости (nв nн), коэффициент глинистости (Кгл), коэффициент пористости (Кп), петрофизические параметры (а, b) связи коэффициента остаточной водонасыщенности и отношения объемной глинистости к пористости, коэффициент остаточной нефтенасыщенность (Кно), далее рассчитывают коэффициент остаточного водонасыщения Кво=а·(Кгл/Кп)+b, после чего вычисляют коэффициент обводненности притока (Коп) по следующей формулеA method for determining the water cut coefficient and composition of an oil well inflow, including conducting geophysical well surveys (GIS) using pulsed neutron-gamma spectrometric logging, determining the component composition of rocks, including porosity and current oil saturation coefficient (K n ), characterized in that the collection is preliminarily prepared core samples from reservoirs uncovered by reference wells, the results of the study of which determine: current water saturation (K in ), coefficient factors of relative phase permeability for oil and water (K ' pr K K prv ), exponential values of relative water and oil permeability (n to n n ), clay factor (K hl ), porosity coefficient (K p ), petrophysical parameters (а , b) the coupling coefficient of the residual water saturation and the ratio of bulk clay porosity, the ratio of the residual oil saturation (C HO), then calculate the coefficient of the residual water saturation K in = a · (K hl / K n) + b, then calculating the water cut rate of inflow (K op) on the following formula К о п = К п р в ' [ 1 − К н − К в о 1 − К в о − К н о ] n в μ н К п р н ' [ К н − К н о 1 − К в о − К н о ] n н μ в + К п р в ' [ 1 − К н − К в о 1 − К в о − К н о ] n в μ н
Figure 00000001
 , TO about P = TO P R at '' [ one - TO n - TO at about one - TO at about - TO n about ] n at μ n TO P R n '' [ TO n - TO n about one - TO at about - TO n about ] n n μ at + TO P R at '' [ one - TO n - TO at about one - TO at about - TO n about ] n at μ n
Figure 00000001
 , где Кн - коэффициент текущего нефтенасыщения, Kво - коэффициент остаточного водонасыщения, Кно - коэффициент остаточной нефтенасыщености, К'прн - коэффициент относительной фазовой проницаемости по нефти, К'прв - коэффициент относительной фазовой проницаемости по воде, nв - экспоненциальное значение относительной водопроницаемости, nн - экспоненциальное значение относительной нефтепроницаемости µн - коэффициент динамической вязкости нефти, µв - коэффициент динамической вязкости воды, далее по полученному коэффициенту обводненности проводят оценку ожидаемого состава притока. where K n is the coefficient of current oil saturation, K in is the coefficient of residual water saturation, K but is the coefficient of residual oil saturation, K ' prn is the coefficient of relative phase permeability for oil, K' prv is the coefficient of relative phase permeability for water, n in is the exponential value of the relative permeability, n n - the exponential value of the relative oil permeability µ n is the coefficient of dynamic viscosity of oil, µ in is the coefficient of dynamic viscosity of water, then according to the obtained water cut coefficient p assess the expected composition of the inflow.
RU2012113376/03A 2012-04-06 2012-04-06 Method for determination of water cut factor and composition of oil well influx RU2505676C2 (en)

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PCT/RU2012/000329 WO2013151455A1 (en) 2012-04-06 2012-04-26 Method for determining the water encroachment factor and the influx composition of an oil well

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CN113552036A (en) * 2020-04-26 2021-10-26 中国石油天然气股份有限公司 Method and device for determining oil-water relative permeability of medium-low pore permeability reservoir

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CN104141490B (en) * 2014-07-17 2016-08-31 中国石油天然气股份有限公司 There are the judgement of Gas Reservoirs individual well water enchroachment (invasion) situation and gas well production yield control method and device
CN104265281B (en) * 2014-10-08 2017-01-11 成都北方石油勘探开发技术有限公司 Method for predicting well yield of sealed, unsaturated oil reservoirs through elastic driving water-flooding extraction
CN104453874B (en) * 2014-10-23 2017-04-12 中国石油天然气集团公司 Glutenite reservoir oil saturation calculation method based on nuclear magnetic resonance
RU2632800C2 (en) * 2016-03-09 2017-10-09 Государственное бюджетное образовательное учреждение высшего образования "Альметьевский государственный нефтяной институт" Method for determining actual oil saturation factor in well when developing oil-bearing formation
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CN113552036A (en) * 2020-04-26 2021-10-26 中国石油天然气股份有限公司 Method and device for determining oil-water relative permeability of medium-low pore permeability reservoir

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