CN105974474B - A kind of method for the reservoir pore space Types Assessment replaced based on hole - Google Patents

A kind of method for the reservoir pore space Types Assessment replaced based on hole Download PDF

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CN105974474B
CN105974474B CN201610533003.0A CN201610533003A CN105974474B CN 105974474 B CN105974474 B CN 105974474B CN 201610533003 A CN201610533003 A CN 201610533003A CN 105974474 B CN105974474 B CN 105974474B
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msub
reservoir
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modulus
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CN105974474A (en
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张佳佳
印兴耀
吴国忱
张广智
张繁昌
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China University of Petroleum East China
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    • G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
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Abstract

The present invention relates to the method for the reservoir pore space Types Assessment replaced based on hole, comprise the following steps：According to the velocity of longitudinal wave, shear wave velocity and density of known reservoir, the saturated rock modulus of elasticity that reservoir contains original hole Class1 is calculated；The modulus of elasticity of reservoir rock matrix minerals component and the modulus of elasticity of pore-fluid constituent are chosen, with reference to porosity, saturation degree and mineral constituent volume content, the modulus of elasticity of calculating reservoir rock matrix；Calculate the rock matrix modulus of elasticity that reservoir contains original hole Class1；The pore components of reservoir when inverting contains porosity type 1；By given new pore components, original hole Class1 is substituted for porosity type 2；Calculate the new velocity of longitudinal wave of the reservoir after replacing, shear wave velocity；Reservoir velocity of longitudinal wave, the situation of change of shear wave velocity before and after contrast is replaced, carry out reservoir pore space Types Assessment.The present invention is better able to portray reservoir pore space type, is more coincide with actual true reservoir.

Description

A kind of method for the reservoir pore space Types Assessment replaced based on hole
Technical field
The present invention relates to Exploration of Oil And Gas technical field, more particularly to a kind of method of reservoir pore space Types Assessment.
Background technology
With deepening continuously for oil-gas exploration and development, the complicated reservoirs such as fracture, igneous rock and shale have become oil The major fields produced in gas increasing the storage.These complicated reservoirs often develop a variety of porosity types, such as matrix pores, crack and hole Deng.The difficult point of complicated reservoirs prediction seeks to find the High-quality Reservoir of high recoverable reserves and high economic value, and porosity type is An important factor for influenceing complicated reservoirs oil and gas reserves and production capacity.Therefore, porosity type evaluation is that complicated reservoirs prediction and fluid are known Other key.
But the relation between the speed of complicated reservoirs and porosity type is extremely complex.Such as identical pore size and fluid Composition, different aperture type carbonate reservoir between speed difference can reach 2500m/s.Therefore, reservoir speed is utilized The key problem that degree carries out porosity type evaluation is exactly to describe the relation between porosity type and speed parameter.Earthquake rock physicses Theory is exactly the relation for being used for establishing between porosity type and reservoir velocities, and Gassmann equation is exactly that a kind of conventional utilizing is stored up Interval velocity evaluates the instrument of porosity type.
In application Gassmann equation carries out rock physicses modeling process to reservoir, reservoir rock skeleton how is determined Modulus of elasticity is very crucial.Reservoir rock skeleton modulus of elasticity can typically pass through laboratory measurement, empirical model or equivalent Jie Matter model is calculated.The modulus of elasticity for calculating reservoir rock skeleton at present generally has following several method：
When directly in the p-and s-wave velocity of experimental determination reservoir rock skeleton and density etc., and then reservoir is calculated The modulus of elasticity (Murphy, 1984) of rock matrix, this method needs special laboratory to be measured, and to obtain in advance Drill cores, so when not possessing in experiment condition or studied work area without core sample, this method failure；
Next to that using EFFECTIVE MEDIUM THEORY, as differential equivalent medium mode (Norris, 1985；Zimmermann, 1985；Berryman, 1992；Li and Zhang, 2010,2011),Model (Kuster and 1974) it and self-compatibility approximate (Wu, 1966, Berryman, 1980) etc., may serve to calculate the springform of reservoir rock skeleton Amount, but the factor that these theoretical models consider is numerous, tends to rely on the hypothesis of model；
Also it is exactly to utilize empirical equation, many scholars establish reservoir porosity, Rock Matrix modulus of elasticity and rock Empirical equation between skeleton modulus of elasticity.In production application, most easy method is empirical equation, particularly works as work Without drilling and coring delivery data and during the data of petrophysics experiment room in area, this method tool has an enormous advantage.Such as Nur etc. is carried The concept of Critical porosity is gone out, has been established using Critical porosity between reservoir rock skeleton and Rock Matrix modulus of elasticity Linear relationship (Nur etc., 1992).But classical Critical porosity model does not establish reservoir rock skeleton and porosity type Between relation, can not thus characterize influence of the porosity type to reservoir rock skeleton modulus of elasticity, and then can not be stored up Layer porosity type evaluation.In addition, these empirical models or empirical equation may be appropriate only for a certain types of reservoir, it can not be promoted His reservoir, simple application empirical model can bring very big error；These empirical models are assumed excessively simple simultaneously, with actual storage Layer porosity type is not met, it is difficult to reflects the porosity type feature of actual reservoir.
The content of the invention
The present invention characterizes the hole of reservoir pore space type using pore shape Critical porosity model according to reservoir velocities inverting Gap aspect ratio parameter, change pore components parameter using pore shape Critical porosity model, by the original porosity type of reservoir Another new porosity type is substituted for, contrast porosity type replaces it the situation of change of rear reservoir velocities, so as to be stored up Layer porosity type evaluation.
In order to solve the above technical problems, the technical proposal of the invention is realized in this way：A kind of storage replaced based on hole The method of layer porosity type evaluation, it comprises the following steps：
Step 1, according to the velocity of longitudinal wave, shear wave velocity and density of known reservoir, calculate reservoir and contain original porosity type 1 saturated rock modulus of elasticity；Choose the modulus of elasticity of reservoir rock matrix minerals component and the bullet of pore-fluid constituent Property modulus, with reference to porosity, saturation degree and mineral constituent volume content, calculate the modulus of elasticity of reservoir rock matrix；Calculate storage Layer contains the rock matrix modulus of elasticity of original hole Class1；The pore components of reservoir when inverting contains porosity type 1；
Step 2, by given new pore components, the original hole Class1 of reservoir is substituted for another new hole Gap type 2；Calculate the new velocity of longitudinal wave of the reservoir after porosity type is replaced, shear wave velocity；
Step 3, reservoir velocity of longitudinal wave, the situation of change of shear wave velocity before and after contrast porosity type is replaced, carries out reservoir hole Gap Types Assessment.
Preferably, step 1 comprises the following steps：
Step 1-1, collect velocity of longitudinal wave, shear wave velocity, density, porosity, mineral constituent volume content and the stream of reservoir Body saturation parameters；
Step 1-2, according to formula (1) and (2) calculate saturated rock bulk modulus that reservoir contains original hole Class1 and Modulus of shearing：
In formula (1) and (2), VP1It is velocity of longitudinal wave, VS1It is shear wave velocity, ρsat1It is density, Ksat1、μsat1Contain respectively There are the saturated rock bulk modulus and modulus of shearing of original hole Class1；
Step 1-3, choose the modulus of elasticity of reservoir rock matrix minerals component and the springform of pore-fluid constituent Amount, with reference to mineral constituent volume content and saturation degree, according to the volume mould of formula (3), (4) and (5) calculating reservoir rock matrix The bulk modulus of amount and modulus of shearing and pore-fluid：
In formula, KmIt is the bulk modulus of reservoir rock matrix, μmIt is the modulus of shearing of reservoir rock matrix, KflIt is hole stream The bulk modulus of body, KiIt is the bulk modulus of i-th kind of mineral constituent, μiIt is the modulus of shearing of i-th kind of mineral constituent, fiIt is i-th kind The volume content of mineral constituent, meetKoil, Kgas, KwaterRespectively oil, the bulk modulus of gas and water, Soil, Sgas, SwaterRespectively oil, the saturation degree of gas and water, and meet Soil+Sgas+Swater=1；
Step 1-4, the bulk modulus of the reservoir rock skeleton containing original hole Class1 is calculated using formula (6) and (7) Kdry1With modulus of shearing μdry1：
μdry1=μsat1 (7)
In formula (6) and (7), Kdry1、μdry1It is the volume mould of the reservoir rock skeleton containing original hole Class1 respectively Amount and modulus of shearing, φ are the porositys of reservoir；
Step 1-5, the pore components α of reservoir when containing original hole Class1 using formula (8) inverting1：
In formula (8),Pmi(α1) it is the original hole Class1 of reservoir and reservoir rock Polarization factor between ground mass matter, it is pore components α1Function.
Preferably, step 2 comprises the following steps：
Step 2-1, it is α to give new pore components2, the original hole Class1 of reservoir is replaced using formula (9) and (10) Porosity type 2 is changed to, calculates the bulk modulus and modulus of shearing of the reservoir rock skeleton containing porosity type 2：
In formula (9) and (10), Kdry2、μdry2Be respectively the reservoir rock skeleton containing porosity type 2 bulk modulus and Modulus of shearing, Pmi(α2) and Qmi(α2) polarization factor between reservoir pore space type 2 and reservoir rock matrix, it is pore components α2Letter Number；
Step 2-2, pore-fluid is added into the reservoir containing porosity type 2 using formula (11), (12) and (13), counted Calculate the bulk modulus K of reservoir saturated rocksat2, modulus of shearing μsat2And density psat2：
μsat2=μdry2 (12)
ρsat2=ρsat1 (13)
In formula (11), (12) and (13), Ksat2、μsat2And ρsat2Reservoir saturated rock respectively containing porosity type 2 Bulk modulus, modulus of shearing and density；
Step 2-3, using formula (14) and (15) calculate the reservoir saturated rock containing porosity type 2 velocity of longitudinal wave and Shear wave velocity：
In formula (14) and (15), VP2、VS2Be respectively the reservoir saturated rock containing porosity type 2 velocity of longitudinal wave and Shear wave velocity.
Preferably, step 3 comprises the following steps：
Step 3-1, the velocity of longitudinal wave difference and horizontal stroke of reservoir before and after porosity type is replaced are calculated according to formula (16) and (17) Wave velocity difference：
ΔVP=(VP2-VP1)/VP1 (16)
ΔVS=(VS2-VS1)/VS1 (17)
In formula (16) and (17), Δ VP、ΔVSIt is the velocity of longitudinal wave difference and horizontal stroke of reservoir before and after porosity type is replaced respectively Wave velocity difference；
Step 3-2, the velocity of longitudinal wave discrepancy delta V of front and rear reservoir is replaced using porosity typePWith shear wave velocity discrepancy delta VSCome Reservoir pore space type is evaluated, if velocity of longitudinal wave discrepancy delta VPWith shear wave velocity discrepancy delta VSLess than 20%, illustrate in original reservoir Containing more porosity type 2, otherwise illustrate to contain less porosity type 2 in original reservoir.
Preferably, original porosity type is substituted for hole, new pore components α2Value is between 0.8~1.0.
Preferably, original porosity type is substituted for crack, new pore components α2Value is 0.0001~0.01 Between.
The method that the present invention evaluates reservoir pore space type according to hole replacement, breach conventional empirical model such as classics Critical porosity model does not consider the limitation that porosity type influences, establishes the relation between porosity type and reservoir velocities, more Reservoir pore space type can be portrayed by adding, and more be coincide with actual true reservoir, making up conventional empirical model can not describing reservoir The deficiency of porosity type.
The method that the present invention evaluates reservoir pore space type according to hole replacement, is to utilize pore shape Critical porosity mould Type calculates reservoir rock skeleton modulus of elasticity, has general applicability, avoids conventional empirical model and be only applicable to specific grind The defects of studying carefully area and can not promoting.
The present invention according to hole replacement come evaluate the method for reservoir pore space type can obtain it is more identical with actual reservoir The speed difference of reservoir before and after rock matrix modulus of elasticity, and hole replacement.Utilize speed difference, it is possible to carry out reservoir hole Gap Types Assessment.
Brief description of the drawings
Fig. 1 is a kind of flow chart of the method for the reservoir pore space Types Assessment replaced based on hole of the present invention.
Fig. 2 is log of certain oil field containing gas well.
Fig. 3 be by reservoir saturated rock of the calculating that log is calculated containing porosity type 1 bulk modulus and Modulus of shearing.
Fig. 4 is the bulk modulus and modulus of shearing and the bulk modulus of pore-fluid for calculating reservoir rock matrix.
Fig. 5 is to calculate the bulk modulus containing the reservoir rock skeleton of porosity type 1 using backward Gassmann equation and cut Shear modulu.
Fig. 6 is the hole that reservoir during containing porosity type 1 is calculated using the pore shape Critical porosity model of the present invention Aspect ratio.
Fig. 7 is that reservoir pore space Class1 is replaced with into porosity type using the pore shape Critical porosity model of the present invention 2, calculate the bulk modulus and modulus of shearing of the reservoir rock skeleton containing porosity type 2.
Fig. 8 is that pore-fluid is added into the reservoir containing porosity type 2 using Gassmann equation, calculates reservoir saturation The bulk modulus and modulus of shearing of rock.
Fig. 9 is the velocity of longitudinal wave and shear wave velocity for calculating the reservoir saturated rock containing porosity type 2.
Figure 10 is the velocity of longitudinal wave difference and shear wave velocity difference for calculating reservoir before and after porosity type is replaced.
Embodiment
The invention will be further described with specific embodiment below in conjunction with the accompanying drawings, so that those skilled in the art can be with It is better understood from the present invention and can be practiced, but illustrated embodiment is not as a limitation of the invention.
Essential core of the present invention has three aspects：First, velocity of longitudinal wave, shear wave velocity, density, the hole of reservoir known to basis The parameters such as degree, saturation degree and mineral constituent volume content (i.e. shale content), utilize Gassmann equation and the hole of the present invention The relation that shape Critical porosity model is established between various parameters, the hole of reservoir pore space type is characterized by reservoir velocities inverting Aspect ratio parameter；Second, changing reservoir pore space aspect ratio parameter using neoteric pore shape Critical porosity model, will store up Layer original porosity type is substituted for another new porosity type, obtains the reservoir velocities after porosity type is replaced；Third, pair The situation of change of reservoir velocities before and after being replaced than porosity type, carries out reservoir pore space Types Assessment.
As shown in figure 1, a kind of method for the reservoir pore space Types Assessment replaced based on hole of the present invention, including following step Suddenly：
Step 1, according to the velocity of longitudinal wave, shear wave velocity and density of known reservoir, calculate reservoir and contain original porosity type 1 saturated rock modulus of elasticity；Choose the modulus of elasticity of reservoir rock matrix minerals component and the bullet of pore-fluid constituent Property modulus, with reference to porosity, saturation degree and mineral constituent volume content, calculate the modulus of elasticity of reservoir rock matrix；Calculate storage Layer contains the rock matrix modulus of elasticity of original hole Class1；The pore components ginseng of reservoir when inverting contains porosity type 1 Number；
Step 2, by given new pore components parameter, it is new that the original hole Class1 of reservoir is substituted for another Porosity type 2；Calculate the new velocity of longitudinal wave of the reservoir after porosity type is replaced, shear wave velocity；
Step 3, reservoir velocity of longitudinal wave, the situation of change of shear wave velocity before and after contrast porosity type is replaced, carries out reservoir hole Gap Types Assessment.
Specifically, step 1 may include steps of：
Step 1-1, collect velocity of longitudinal wave, shear wave velocity, density, porosity, mineral constituent volume content and the stream of reservoir The parameters such as body saturation degree.
Step 1-2, according to the velocity of longitudinal wave V of reservoirP1, shear wave velocity VS1And density psat1Calculate reservoir and contain original hole The saturated rock bulk modulus K of Class1sat1With modulus of shearing μsat1(it is assumed that the original hole Class1 of reservoir is replaced by porosity type 2 Change, its corresponding parameter subscript is distinguished by with 1,2 respectively)：
Step 1-3, choose the modulus of elasticity of reservoir rock matrix minerals component and the springform of pore-fluid constituent Amount, with reference to mineral constituent volume content and saturation degree etc., the bulk modulus K of calculating reservoir rock matrixmWith modulus of shearing μmAnd hole The bulk modulus K of clearance flow bodyfl。
In formula, KiIt is the bulk modulus of i-th kind of mineral constituent, μiIt is the modulus of shearing of i-th kind of mineral constituent, fiIt is i-th kind The volume content of mineral constituent, meetKoil, Kgas, KwaterRespectively oil, the bulk modulus of gas and water, Soil, Sgas, SwaterRespectively oil, the saturation degree of gas and water, and meet Soil+Sgas+Swater=1.
Step 1-4, the bulk modulus K of reservoir rock skeleton is calculated using backward Gassmann equationdry1And modulus of shearing μdry1：
μdry1=μsat1 (7)
In formula, φ is the porosity of reservoir.
Step 1-5, the hole of reservoir when containing porosity type 1 using neoteric pore shape Critical porosity model inversion Gap aspect ratio α1：
In formula,Pmi(α1) between reservoir pore space Class1 and reservoir rock matrix Polarization factor, be pore components α1Function.Using non-linear global optimizing Algorithm for Solving formula (8), the hole being calculated Gap aspect ratio α1Can characterizes the original hole Class1 of reservoir.Wherein, Pmi(α1) expression may be referred to by G The books The Rock that the Cambridge University Press that Mavko, T Mukerji, J Dvorkin etc. writes are published Physics Handbook:Formula in Tools for Seismic Analysis of Porous Media in page 127.
The critical pore angle value of rock and the hole of rock are indulged defined in the pore shape Critical porosity model of the present invention Functional relation between horizontal ratio, it is exactlyWith
Specifically, step 2 may include steps of：
Step 2-1, it is α to give new pore components2, will be stored up using neoteric pore shape Critical porosity model Layer porosity type 1 replaces with porosity type 2, calculates the bulk modulus K of the reservoir rock skeleton containing porosity type 2dry2With cut Shear modulu μdry2：
In formula, Pmi(α2) and Qmi(α2) polarization factor between reservoir pore space type 2 and reservoir rock matrix, it is pore components α2Letter Number.Wherein, Pmi(α2) and Qmi(α2) expression may be referred to what is write by G Mavko, T Mukerji, J Dvorkin etc. The books The Rock Physics Handbook that Cambridge University Press are published:Tools for Formula in Seismic Analysis of Porous Media in page 127.
At this moment original hole Class1 (the pore components α of reservoir1) just having been replaced by new porosity type 2, (hole is indulged It is horizontal to compare α2)。α2It is that original porosity type (is used into pore components α1Characterize) it is substituted for new porosity type (with hole in length and breadth Compare α2Characterize), can arbitrarily it give, if original porosity type is substituted for into hole, then α2=0.8, because the hole of hole Ripple is larger in length and breadth for gap, typically between 0.8~1.0；If original porosity type is substituted for crack, then α2=0.01, Because ripple is larger in length and breadth for the hole in crack, typically between 0.0001~0.01.
Step 2-2, pore-fluid is added into the reservoir containing porosity type 2 using Gassmann equation, calculate reservoir The bulk modulus K of saturated rocksat2, modulus of shearing μsat2And density psat2：
μsat2=μdry2 (12)
ρsat2=ρsat1 (13)
Step 2-3, calculate the velocity of longitudinal wave V of the reservoir saturated rock containing porosity type 2P2With shear wave velocity VS2：
Specifically, step 3 may include steps of：
Step 3-1, calculate the velocity of longitudinal wave discrepancy delta V of reservoir before and after porosity type is replacedPWith shear wave velocity discrepancy delta VS：
ΔVP=(VP2-VP1)/VP1 (16)
ΔVS=(VS2-VS1)/VS1 (17)
Step 3-2, the velocity of longitudinal wave discrepancy delta V of front and rear reservoir is replaced using porosity typePWith shear wave velocity discrepancy delta VSCome Reservoir pore space type is evaluated, if velocity of longitudinal wave discrepancy delta VPWith shear wave velocity discrepancy delta VSLess than 20%, illustrate in original reservoir Containing more porosity type 2, otherwise illustrate to contain less porosity type 2 in original reservoir.
Fig. 2 is log of certain oil field containing gas well, including reservoir velocity of longitudinal wave, shear wave velocity, density, porosity, mud Matter content and gas saturation.These data are the input data illustrated by step 1-1.
Fig. 3 is the reservoir saturated rock containing porosity type 1 calculated by reservoir velocity of longitudinal wave, shear wave velocity and density Bulk modulus and modulus of shearing, they be by formula (1) in step 1-2 of reservoir velocity of longitudinal wave, shear wave velocity and density and (2) it is calculated.
Fig. 4 is the bulk modulus and modulus of shearing and the bulk modulus of pore-fluid for calculating reservoir rock matrix, and they are By formula (3) of the modulus of elasticity of reservoir shale content, porosity, fluid saturation and mineral composition in step step 1-3, (4) it is calculated with (5).Here the bulk modulus of dolomite mineral, modulus of shearing and density take respectively 77GPa, 32GPa and 2.71g/cm3, bulk modulus, modulus of shearing and the density of shale take 25GPa, 9GPa and 2.56g/cm3 respectively；The volume mould of water Amount, modulus of shearing and density take 2.29GPa, 0GPa and 1.0g/cm3, bulk modulus, modulus of shearing and the density difference of gas respectively Take 0.0208GPa, 0GPa and 0.00001g/cm3.
Fig. 5 is to calculate the bulk modulus containing original hole Class1 reservoir rock skeleton using backward Gassmann equation And modulus of shearing, they are the formula in step 1-4 by the modulus of elasticity of reservoir saturated rock, Rock Matrix and pore-fluid (6) it is calculated with (7).
Fig. 6 is that reservoir hole when containing original hole Class1 is calculated using neoteric pore shape Critical porosity model Gap aspect ratio, it is according to step using non-linear global optimizing algorithm by the bulk modulus of reservoir rock skeleton and Rock Matrix Formula (8) inverting in 1-5 obtains.
Fig. 7 be the original hole Class1 of reservoir is replaced with using neoteric pore shape Critical porosity model it is new Porosity type 2, the bulk modulus and modulus of shearing of the reservoir rock skeleton containing porosity type 2 are calculated, they are by reservoir rock The formula (9) and (10) of the bulk modulus of ground mass matter and new pore components in step 2-1 are calculated, here hole class The pore components parameter of type 2 takes 0.8, characterizes hole.
Fig. 8 is to add pore-fluid into the reservoir containing porosity type 2 using Gassmann equation, calculates new reservoir Saturated rock bulk modulus and modulus of shearing.They are the bulk modulus and new reservoir rock skeleton by reservoir rock matrix Formula (11), (12) and (13) of the modulus of elasticity in step 2-2 is calculated.
Fig. 9 is the velocity of longitudinal wave and shear wave velocity for calculating the reservoir saturated rock containing porosity type 2, and they are by new The formula (14) and (15) of reservoir saturated rock bulk modulus, modulus of shearing and density in step 2-3 are calculated.
Figure 10 is the velocity of longitudinal wave difference and shear wave velocity difference for calculating reservoir before and after porosity type is replaced, and they are by hole Formula (16) and (17) of the velocity of longitudinal wave and shear wave velocity of reservoir in step 3-1 are calculated before and after gap type is replaced.From Figure 10 can see, velocity of longitudinal wave at 2075~2078m, 2687~2697m, 2700~2712m and 2736~2758m and Shear wave velocity difference illustrates the Reservoir Section hole agensis more than 20%；And velocity of longitudinal wave at other reservoir intervals of the well 20% is not above with shear wave velocity difference, illustrates that the Reservoir Section hole is developed.Development refers to that hole accounts for the volume hundred of total pore space Divide comparison more, generally more than 50%；The volume basis that agensis finger-hole hole accounts for total pore space is fewer, and generally below 50%.
Embodiment described above is only to absolutely prove preferred embodiment that is of the invention and being lifted, protection model of the invention Enclose not limited to this.The equivalent substitute or conversion that those skilled in the art are made on the basis of the present invention, in the present invention Protection domain within.Protection scope of the present invention is defined by claims.

Claims (5)

  1. A kind of 1. method for the reservoir pore space Types Assessment replaced based on hole, it is characterised in that comprise the following steps：
    Step 1, according to the velocity of longitudinal wave, shear wave velocity and density of known reservoir, calculate reservoir and contain original hole Class1 Saturated rock modulus of elasticity；Choose the modulus of elasticity of reservoir rock matrix minerals component and the springform of pore-fluid constituent Amount, with reference to porosity, saturation degree and mineral constituent volume content, the modulus of elasticity of calculating reservoir rock matrix；Reservoir is calculated to contain There is the rock matrix modulus of elasticity of original hole Class1；The pore components of reservoir when inverting contains porosity type 1；
    Step 2, by given new pore components, the original hole Class1 of reservoir is substituted for another new hole class Type 2；Calculate the new velocity of longitudinal wave of the reservoir after porosity type is replaced, shear wave velocity；
    Step 3, reservoir velocity of longitudinal wave, the situation of change of shear wave velocity before and after contrast porosity type is replaced, carries out reservoir pore space class Type is evaluated；
    Wherein, the step 3 comprises the following steps：
    Step 3-1, the velocity of longitudinal wave difference of reservoir and shear wave speed before and after porosity type is replaced are calculated according to formula (16) and (17) Spend difference：
    ΔVP=(VP2-VP1)/VP1 (16)
    ΔVS=(VS2-VS1)/VS1 (17)
    In formula (16) and (17), Δ VP、ΔVSIt is the velocity of longitudinal wave difference of reservoir and shear wave speed before and after porosity type is replaced respectively Spend difference；
    Step 3-2, the velocity of longitudinal wave discrepancy delta V of front and rear reservoir is replaced using porosity typePWith shear wave velocity discrepancy delta VSTo evaluate Reservoir pore space type, if velocity of longitudinal wave discrepancy delta VPWith shear wave velocity discrepancy delta VSLess than 20%, illustrate to contain in original reservoir More porosity type 2, otherwise illustrate to contain less porosity type 2 in original reservoir.
  2. 2. according to the method for claim 1, it is characterised in that step 1 comprises the following steps：
    Step 1-1, velocity of longitudinal wave, shear wave velocity, density, porosity, mineral constituent volume content and the fluid for collecting reservoir are satisfied With degree parameter；
    Step 1-2, saturated rock bulk modulus and the shearing of original hole Class1 are contained according to formula (1) and (2) calculating reservoir Modulus：
    <mrow> <msub> <mi>K</mi> <mrow> <mi>s</mi> <mi>a</mi> <mi>t</mi> <mn>1</mn> </mrow> </msub> <mo>=</mo> <msub> <mi>&amp;rho;</mi> <mrow> <mi>s</mi> <mi>a</mi> <mi>t</mi> <mn>1</mn> </mrow> </msub> <mrow> <mo>(</mo> <msubsup> <mi>V</mi> <mrow> <mi>P</mi> <mn>1</mn> </mrow> <mn>2</mn> </msubsup> <mo>-</mo> <mfrac> <mn>4</mn> <mn>3</mn> </mfrac> <msubsup> <mi>V</mi> <mrow> <mi>S</mi> <mn>1</mn> </mrow> <mn>2</mn> </msubsup> <mo>)</mo> </mrow> <mo>-</mo> <mo>-</mo> <mo>-</mo> <mrow> <mo>(</mo> <mn>1</mn> <mo>)</mo> </mrow> </mrow>
    <mrow> <msub> <mi>&amp;mu;</mi> <mrow> <mi>s</mi> <mi>a</mi> <mi>t</mi> <mn>1</mn> </mrow> </msub> <mo>=</mo> <msub> <mi>&amp;rho;</mi> <mrow> <mi>s</mi> <mi>a</mi> <mi>t</mi> <mn>1</mn> </mrow> </msub> <msubsup> <mi>V</mi> <mrow> <mi>S</mi> <mn>1</mn> </mrow> <mn>2</mn> </msubsup> <mo>-</mo> <mo>-</mo> <mo>-</mo> <mrow> <mo>(</mo> <mn>2</mn> <mo>)</mo> </mrow> </mrow>
    In formula (1) and (2), VP1It is velocity of longitudinal wave, VS1It is shear wave velocity, ρsat1It is density, Ksat1、μsat1It is containing original respectively The saturated rock bulk modulus and modulus of shearing of beginning porosity type 1；
    Step 1-3, choose the modulus of elasticity of reservoir rock matrix minerals component and the modulus of elasticity of pore-fluid constituent, knot Mineral constituent volume content and saturation degree are closed, the bulk modulus of reservoir rock matrix is calculated according to formula (3), (4) and (5) and cut The bulk modulus of shear modulu and pore-fluid：
    <mrow> <msub> <mi>K</mi> <mi>m</mi> </msub> <mo>=</mo> <mrow> <mo>(</mo> <munderover> <mo>&amp;Sigma;</mo> <mrow> <mi>i</mi> <mo>=</mo> <mn>1</mn> </mrow> <mi>N</mi> </munderover> <msub> <mi>f</mi> <mi>i</mi> </msub> <msub> <mi>K</mi> <mi>i</mi> </msub> <mo>+</mo> <mn>1</mn> <mo>/</mo> <munderover> <mo>&amp;Sigma;</mo> <mrow> <mi>i</mi> <mo>=</mo> <mn>1</mn> </mrow> <mi>N</mi> </munderover> <mfrac> <msub> <mi>f</mi> <mi>i</mi> </msub> <msub> <mi>K</mi> <mi>i</mi> </msub> </mfrac> <mo>)</mo> </mrow> <mo>/</mo> <mn>2</mn> <mo>-</mo> <mo>-</mo> <mo>-</mo> <mrow> <mo>(</mo> <mn>3</mn> <mo>)</mo> </mrow> </mrow>
    <mrow> <msub> <mi>&amp;mu;</mi> <mi>m</mi> </msub> <mo>=</mo> <mrow> <mo>(</mo> <munderover> <mo>&amp;Sigma;</mo> <mrow> <mi>i</mi> <mo>=</mo> <mn>1</mn> </mrow> <mi>N</mi> </munderover> <msub> <mi>f</mi> <mi>i</mi> </msub> <msub> <mi>&amp;mu;</mi> <mi>i</mi> </msub> <mo>+</mo> <mn>1</mn> <mo>/</mo> <munderover> <mo>&amp;Sigma;</mo> <mrow> <mi>i</mi> <mo>=</mo> <mn>1</mn> </mrow> <mi>N</mi> </munderover> <mfrac> <msub> <mi>f</mi> <mi>i</mi> </msub> <msub> <mi>&amp;mu;</mi> <mi>i</mi> </msub> </mfrac> <mo>)</mo> </mrow> <mo>/</mo> <mn>2</mn> <mo>-</mo> <mo>-</mo> <mo>-</mo> <mrow> <mo>(</mo> <mn>4</mn> <mo>)</mo> </mrow> </mrow>
    <mrow> <mfrac> <mn>1</mn> <msub> <mi>K</mi> <mrow> <mi>f</mi> <mi>l</mi> </mrow> </msub> </mfrac> <mo>=</mo> <mfrac> <msub> <mi>S</mi> <mrow> <mi>o</mi> <mi>i</mi> <mi>l</mi> </mrow> </msub> <msub> <mi>K</mi> <mrow> <mi>o</mi> <mi>i</mi> <mi>l</mi> </mrow> </msub> </mfrac> <mo>+</mo> <mfrac> <msub> <mi>S</mi> <mrow> <mi>g</mi> <mi>a</mi> <mi>s</mi> </mrow> </msub> <msub> <mi>K</mi> <mrow> <mi>g</mi> <mi>a</mi> <mi>s</mi> </mrow> </msub> </mfrac> <mo>+</mo> <mfrac> <msub> <mi>S</mi> <mrow> <mi>w</mi> <mi>a</mi> <mi>t</mi> <mi>e</mi> <mi>r</mi> </mrow> </msub> <msub> <mi>K</mi> <mrow> <mi>w</mi> <mi>a</mi> <mi>t</mi> <mi>e</mi> <mi>r</mi> </mrow> </msub> </mfrac> <mo>-</mo> <mo>-</mo> <mo>-</mo> <mrow> <mo>(</mo> <mn>5</mn> <mo>)</mo> </mrow> </mrow>
    In formula, KmIt is the bulk modulus of reservoir rock matrix, μmIt is the modulus of shearing of reservoir rock matrix, KflIt is pore-fluid Bulk modulus, KiIt is the bulk modulus of i-th kind of mineral constituent, μiIt is the modulus of shearing of i-th kind of mineral constituent, fiIt is i-th kind of mineral The volume content of component, meetN is the sum of all mineral constituents of rock, Koil, Kgas, KwaterRespectively oily, The bulk modulus of gas and water, Soil, Sgas, SwaterRespectively oil, the saturation degree of gas and water, and meet Soil+Sgas+Swater=1；
    Step 1-4, the bulk modulus K of the reservoir rock skeleton containing original hole Class1 is calculated using formula (6) and (7)dry1 With modulus of shearing μdry1：
    <mrow> <msub> <mi>K</mi> <mrow> <mi>d</mi> <mi>r</mi> <mi>y</mi> <mn>1</mn> </mrow> </msub> <mo>=</mo> <mfrac> <mrow> <msub> <mi>K</mi> <mrow> <mi>s</mi> <mi>a</mi> <mi>t</mi> </mrow> </msub> <mrow> <mo>(</mo> <mfrac> <mrow> <msub> <mi>&amp;phi;K</mi> <mi>m</mi> </msub> </mrow> <msub> <mi>K</mi> <mrow> <mi>f</mi> <mi>l</mi> </mrow> </msub> </mfrac> <mo>+</mo> <mn>1</mn> <mo>-</mo> <mi>&amp;phi;</mi> <mo>)</mo> </mrow> <mo>-</mo> <msub> <mi>K</mi> <mi>m</mi> </msub> </mrow> <mrow> <mfrac> <mrow> <msub> <mi>&amp;phi;K</mi> <mi>m</mi> </msub> </mrow> <msub> <mi>K</mi> <mrow> <mi>f</mi> <mi>l</mi> </mrow> </msub> </mfrac> <mo>+</mo> <mfrac> <msub> <mi>K</mi> <mrow> <mi>s</mi> <mi>a</mi> <mi>t</mi> </mrow> </msub> <msub> <mi>K</mi> <mi>m</mi> </msub> </mfrac> <mo>-</mo> <mn>1</mn> <mo>-</mo> <mi>&amp;phi;</mi> </mrow> </mfrac> <mo>-</mo> <mo>-</mo> <mo>-</mo> <mrow> <mo>(</mo> <mn>6</mn> <mo>)</mo> </mrow> </mrow>
    μdry1=μsat1 (7)
    In formula (6) and (7), Kdry1、μdry1Be respectively the reservoir rock skeleton containing original hole Class1 bulk modulus and Modulus of shearing, φ are the porositys of reservoir；
    Step 1-5, the pore components α of reservoir when containing original hole Class1 using formula (8) inverting1：
    <mrow> <msub> <mi>K</mi> <mrow> <mi>d</mi> <mi>r</mi> <mi>y</mi> <mn>1</mn> </mrow> </msub> <mo>-</mo> <msub> <mi>K</mi> <mi>m</mi> </msub> <mrow> <mo>(</mo> <mn>1</mn> <mo>-</mo> <mfrac> <mi>&amp;phi;</mi> <mrow> <msub> <mi>&amp;phi;</mi> <mrow> <mi>c</mi> <mi>K</mi> </mrow> </msub> <mrow> <mo>(</mo> <msub> <mi>&amp;alpha;</mi> <mn>1</mn> </msub> <mo>)</mo> </mrow> </mrow> </mfrac> <mo>)</mo> </mrow> <mo>=</mo> <mn>0</mn> <mo>-</mo> <mo>-</mo> <mo>-</mo> <mrow> <mo>(</mo> <mn>8</mn> <mo>)</mo> </mrow> </mrow>
    In formula (8),Pmi(α1) it is the original hole Class1 of reservoir and reservoir rock base Polarization factor between matter, it is pore components α1Function.
  3. 3. according to the method for claim 1, it is characterised in that step 2 comprises the following steps：
    Step 2-1, it is α to give new pore components2, the original hole Class1 of reservoir is replaced with using formula (9) and (10) Porosity type 2, calculate the bulk modulus and modulus of shearing of the reservoir rock skeleton containing porosity type 2：
    <mrow> <msub> <mi>K</mi> <mrow> <mi>d</mi> <mi>r</mi> <mi>y</mi> <mn>2</mn> </mrow> </msub> <mo>=</mo> <msub> <mi>K</mi> <mi>m</mi> </msub> <mrow> <mo>(</mo> <mn>1</mn> <mo>-</mo> <mfrac> <mi>&amp;phi;</mi> <mrow> <msub> <mi>&amp;phi;</mi> <mrow> <mi>c</mi> <mi>K</mi> </mrow> </msub> <mrow> <mo>(</mo> <msub> <mi>&amp;alpha;</mi> <mn>2</mn> </msub> <mo>)</mo> </mrow> </mrow> </mfrac> <mo>)</mo> </mrow> <mo>-</mo> <mo>-</mo> <mo>-</mo> <mrow> <mo>(</mo> <mn>9</mn> <mo>)</mo> </mrow> </mrow>
    <mrow> <msub> <mi>&amp;mu;</mi> <mrow> <mi>d</mi> <mi>r</mi> <mi>y</mi> <mn>2</mn> </mrow> </msub> <mo>=</mo> <msub> <mi>&amp;mu;</mi> <mi>m</mi> </msub> <mrow> <mo>(</mo> <mn>1</mn> <mo>-</mo> <mfrac> <mi>&amp;phi;</mi> <mrow> <msub> <mi>&amp;phi;</mi> <mrow> <mi>c</mi> <mi>&amp;mu;</mi> </mrow> </msub> <mrow> <mo>(</mo> <msub> <mi>&amp;alpha;</mi> <mn>2</mn> </msub> <mo>)</mo> </mrow> </mrow> </mfrac> <mo>)</mo> </mrow> <mo>-</mo> <mo>-</mo> <mo>-</mo> <mrow> <mo>(</mo> <mn>10</mn> <mo>)</mo> </mrow> </mrow>
    In formula (9) and (10), Kdry2、μdry2It is bulk modulus and the shearing of the reservoir rock skeleton containing porosity type 2 respectively Modulus, Pmi (α2) and Qmi(α2) polarization factor between reservoir pore space type 2 and reservoir rock matrix, it is pore components α2Function；
    Step 2-2, pore-fluid is added into the reservoir containing porosity type 2 using formula (11), (12) and (13), calculates storage The bulk modulus K of layer saturated rocksat2, modulus of shearing μsat2And density psat2：
    <mrow> <msub> <mi>K</mi> <mrow> <mi>s</mi> <mi>a</mi> <mi>t</mi> <mn>2</mn> </mrow> </msub> <mo>=</mo> <msub> <mi>K</mi> <mrow> <mi>d</mi> <mi>r</mi> <mi>y</mi> <mn>2</mn> </mrow> </msub> <mo>+</mo> <mfrac> <msup> <mrow> <mo>(</mo> <mn>1</mn> <mo>-</mo> <mfrac> <msub> <mi>K</mi> <mrow> <mi>d</mi> <mi>r</mi> <mi>y</mi> <mn>2</mn> </mrow> </msub> <msub> <mi>K</mi> <mi>m</mi> </msub> </mfrac> <mo>)</mo> </mrow> <mn>2</mn> </msup> <mrow> <mfrac> <mi>&amp;phi;</mi> <msub> <mi>K</mi> <mrow> <mi>f</mi> <mi>l</mi> </mrow> </msub> </mfrac> <mo>+</mo> <mfrac> <mrow> <mn>1</mn> <mo>-</mo> <mi>&amp;phi;</mi> </mrow> <msub> <mi>K</mi> <mi>m</mi> </msub> </mfrac> <mo>-</mo> <mfrac> <msub> <mi>K</mi> <mrow> <mi>d</mi> <mi>r</mi> <mi>y</mi> </mrow> </msub> <msubsup> <mi>K</mi> <mi>m</mi> <mn>2</mn> </msubsup> </mfrac> </mrow> </mfrac> <mo>-</mo> <mo>-</mo> <mo>-</mo> <mrow> <mo>(</mo> <mn>11</mn> <mo>)</mo> </mrow> </mrow>
    μsat2=μdry2 (12)
    ρsat2=ρsat1 (13)
    In formula (11), (12) and (13), Ksat2、μsat2And ρsat2The body of reservoir saturated rock respectively containing porosity type 2 Product module amount, modulus of shearing and density；
    Step 2-3, the velocity of longitudinal wave and shear wave of the reservoir saturated rock containing porosity type 2 are calculated using formula (14) and (15) Speed：
    <mrow> <msub> <mi>V</mi> <mrow> <mi>P</mi> <mn>2</mn> </mrow> </msub> <mo>=</mo> <msqrt> <mfrac> <mrow> <mo>(</mo> <msub> <mi>K</mi> <mrow> <mi>s</mi> <mi>a</mi> <mi>t</mi> <mn>2</mn> </mrow> </msub> <mo>+</mo> <mfrac> <mn>4</mn> <mn>3</mn> </mfrac> <msub> <mi>&amp;mu;</mi> <mrow> <mi>s</mi> <mi>a</mi> <mi>t</mi> <mn>2</mn> </mrow> </msub> <mo>)</mo> </mrow> <msub> <mi>&amp;rho;</mi> <mrow> <mi>s</mi> <mi>a</mi> <mi>t</mi> <mn>2</mn> </mrow> </msub> </mfrac> </msqrt> <mo>-</mo> <mo>-</mo> <mo>-</mo> <mrow> <mo>(</mo> <mn>14</mn> <mo>)</mo> </mrow> </mrow>
    <mrow> <msub> <mi>V</mi> <mrow> <mi>S</mi> <mn>2</mn> </mrow> </msub> <mo>=</mo> <msqrt> <mfrac> <msub> <mi>&amp;mu;</mi> <mrow> <mi>s</mi> <mi>a</mi> <mi>t</mi> <mn>2</mn> </mrow> </msub> <msub> <mi>&amp;rho;</mi> <mrow> <mi>s</mi> <mi>a</mi> <mi>t</mi> <mn>2</mn> </mrow> </msub> </mfrac> </msqrt> <mo>-</mo> <mo>-</mo> <mo>-</mo> <mrow> <mo>(</mo> <mn>15</mn> <mo>)</mo> </mrow> </mrow>
    In formula (14) and (15), VP2、VS2It is the velocity of longitudinal wave and shear wave speed of the reservoir saturated rock containing porosity type 2 respectively Degree.
  4. 4. according to the method for claim 3, it is characterised in that original porosity type is substituted for hole, new hole Aspect ratio α2Value is between 0.8~1.0.
  5. 5. according to the method for claim 3, it is characterised in that original porosity type is substituted for crack, new hole Aspect ratio α2Value is between 0.0001~0.01.
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