CN105353419A - Nuclear magnetism capillary pressure curve construction method based on reservoir stratum classification - Google Patents
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Abstract
The invention discloses a nuclear magnetism capillary pressure curve construction method based on reservoir stratum classification. The method includes the steps: according to nuclear magnetic resonance logging data and limited capillary pressure data, obtaining the porosity, the permeability and an T2 geometric mean value curve for the reservoir stratum by means of inversion of the nuclear magnetic resonance logging data; calculating a flow zone index FZI which can reflect the difference of the reservoir stratum by means of the porosity and permeability curve, and utilizing the FZI to classify the reservoir stratum into three types; for every type of reservoir stratum, respectively establishing a function relationship among the wetting phase saturation, the nuclear magnetic resonance porosity Phi and the T2 geometric mean value T2LM under different mercury intrusion pressures; according to the obtained function relationship, calculating the wetting phase saturation under different mercury intrusion pressures, and converting the wetting phase saturation into the mercury intrusion saturation; according to the calculated mercury intrusion saturation and the corresponding mercury intrusion pressure, constructing a nuclear magnetism capillary pressure curve; and according to the nuclear magnetism capillary pressure curve, acquiring pore throat radius distribution, and achieving the aim for continuous quantitative evaluation of the pore structure of the reservoir stratum.
Description
Technical Field
The invention belongs to the field of reservoir evaluation, and particularly relates to a nuclear magnetic capillary pressure curve construction method based on reservoir classification.
Background
The exploration and development process for hyposmosis-tight reservoirs is actually a 'poor medium-to-medium' process, namely, reservoirs with relatively good quality and oil and gas development potential are searched in generally poor formations. The difference between premium and non-reservoir layers is mainly reflected in the pore structure. Good quality reservoirs tend to have better pore structure and pore connectivity, while non-reservoirs tend to have poorer pore structure and pore connectivity. If the pore structure of the reservoir can be quantitatively evaluated, on the basis, the reservoir type is divided, and a high-quality reservoir is determined, so that the method has important significance for improving the exploration efficiency of the hyposmosis-compact reservoir and reducing the development risk.
The most effective data for quantitative evaluation of reservoir pore structure is the capillary pressure curve. By processing the capillary pressure curve, pore-throat radius distribution reflecting the pore size and connectivity of the reservoir can be obtained, so that the reservoir type is divided by utilizing the pore-throat radius distribution to determine a high-quality reservoir. However, the capillary pressure curve data obtained by drilling a core to develop a capillary pressure experiment is very limited, and the purpose of continuously and quantitatively evaluating the pore structure of the reservoir cannot be realized. In order to continuously and quantitatively evaluate the pore structure of the reservoir and search a high-quality reservoir, a method for continuously constructing a capillary pressure curve (called a nuclear magnetic capillary pressure curve) by using nuclear magnetic resonance logging information is proposed by many scholars, and the constructed nuclear magnetic capillary pressure curve is used for replacing a core capillary pressure curve so as to realize the purpose of continuously and quantitatively evaluating the pore structure of the reservoir.
The methods for constructing the pressure curve of the nuclear magnetic capillary by using nuclear magnetic resonance logging data in the currently published documents mainly comprise the following steps:
1. a pseudo capillary pressure curve construction method based on Swanson parameters. A pseudo capillary pressure curve construction method based on Swanson parameters is described in the journal of applied geophysics, 6.2008, article "ANewMethodthod Constretres RevororCapillary PressureureConsurvesUingNMRLogingDataaandActiapplication" by XiaoLiang et al. The method comprises the following basic steps: firstly, establishing a reservoir permeability explanation model based on Swanson parameters according to capillary pressure curve data measured by experiments, and calculating the permeability of a reservoir from nuclear magnetic resonance logging data by using the reservoir permeability explanation model; then, according to morphological characteristics of a capillary pressure curve, establishing a correlation relation between mercury inlet saturation, nuclear magnetism porosity and permeability under different mercury inlet pressures so as to calculate the mercury inlet saturation by using porosity and permeability parameters of rocks, and finally combining the calculated mercury inlet saturation and the calculated mercury inlet pressure to realize the purpose of reconstructing a pseudo capillary pressure curve.
2. Two-dimensional equal-area scale conversion coefficient method. See the article "application of nmr logging in evaluating pore structure of reservoir" made by showa et al in journal of "logging technique" of 2 months in 2009, which states that the use of the second techniqueA method for constructing a nuclear magnetism false capillary pressure curve by a dimensional equal area scale conversion coefficient method. The method comprises the following basic steps: firstly, according to the relation between the pore throat radius and capillary pressure, converting the measured capillary pressure curve into pore throat radius distribution, and utilizing differential similarity principle to define the pore throat radius distribution of each sampleT 2A lateral conversion factor between the spectrum and the corresponding pore throat radius distribution; then, the method of sectional equal area graduation is used to determine the sample of each blockT 2Longitudinal conversion coefficients between spectra and corresponding pore throat radius distributions; and finally, establishing the relationship between the transverse conversion coefficient and the longitudinal conversion coefficient and the porosity and permeability of the rock so as to achieve the aim of constructing a pseudo capillary pressure curve by utilizing nuclear magnetic resonance logging.
3. A piecewise non-linear power function scaling method. Referring to a patent of 'a method for continuously and quantitatively evaluating pore structures of reservoirs by using nuclear magnetic resonance logging data' invented by 1 month of Conlimn, 2010, and the like, a method for constructing a pseudo capillary pressure curve from the nuclear magnetic resonance logging data by adopting a piecewise nonlinear power function calibration method is described. The basic principle is as follows: firstly, a parameter reflecting reservoir difference is calculated according to the porosity and permeability of the rockAnd the parameters are utilized to divide the reservoirs into four types, and different piecewise power functions are respectively adopted to construct a pseudo capillary pressure curve aiming at each type of reservoir. For the first, second and third kinds of reservoirs, a segmentation method is adopted, different power functions are respectively adopted in the large-pore throat section and the small-pore throat section, and for the fourth kind of reservoirs, a single power function is adopted to carry out nuclear magnetic resonanceT 2The spectrum is converted into pore throat radius distribution, and then a pseudo capillary pressure curve is constructed according to the relationship between the pore throat radius and capillary pressure.
The existing nuclear magnetic capillary pressure curve construction method is an empirical statistical method obtained on the basis of rock core experimental analysis, has regional limitation and lacks of theoretical basic support. The applicability of the method is greatly limited, and the method cannot be widely popularized and applied.
Disclosure of Invention
In order to overcome the problem of insufficient theoretical basis of the existing method, the invention provides a nuclear magnetic capillary pressure curve construction method based on reservoir classification on the basis of deep derivation of the classic J function theory and SDR model, and the aim of accurately constructing the nuclear magnetic capillary pressure curve according to the actually measured nuclear magnetic resonance logging data is fulfilled.
In order to solve the problems, the invention adopts the following technical scheme:
according to the NMR logging data and the limited capillary pressure data, firstly, the NMR logging of the reservoir is obtained by inverting the NMR loggingT 2Spectra and corresponding porosities, permeabilities andT 2a geometric mean curve; secondly, calculating a flow unit index FZI reflecting reservoir layer differences by utilizing the porosity and permeability curves, dividing the reservoir layers into three types by utilizing the FZI, and respectively establishing wetting phase saturation and nuclear magnetic resonance porosity under different mercury inlet pressures aiming at each type of reservoir layersφAndT 2geometric mean valueT 2LMCalculating the saturation of the wetting phase under different mercury inlet pressures according to the obtained functional relation, and converting the saturation to obtain the mercury inlet saturation; thirdly, constructing a nuclear magnetic capillary pressure curve according to the calculated mercury inlet saturation and the corresponding mercury inlet pressure; and finally, acquiring the pore throat radius distribution according to the nuclear magnetic capillary pressure curve, and realizing the purpose of continuously and quantitatively evaluating the pore structure of the reservoir.
The method comprises the following steps:
1) determining M mercury inlet pressures on the basis of analyzing the characteristics of a rock core mercury intrusion experiment and the operation process;
2) collecting reservoir layer data by using a nuclear magnetic resonance logging instrument, and inverting the collected data to obtainTo nuclear magnetic resonance loggingT 2Spectrum and reservoir porosity, permeability andT 2a geometric mean curve;
3) calculating a flow unit index FZI reflecting the characteristic difference of the reservoir by using the porosity and permeability curves, and classifying the reservoir by using the FZI according to the following standards: class I reservoir: FZI is more than or equal to 0.22; class II reservoirs: FZI is more than or equal to 0.04 and less than 0.22; class III reservoirs: FZI < 0.04;
4) aiming at three different types of reservoirs, respectively establishing the saturation of the wetting phase and the porosity of the rock under M different mercury inlet pressuresφAndT 2geometric mean valueT 2LMThe function relation between the M wetting phase saturation levels and the M wetting phase saturation levels corresponding to the M mercury inlet pressures are calculated from the nuclear magnetic resonance logging data by utilizing the function relation;
5) converting the calculated saturation of the wetting phase into saturation of the mercury inlet according to the relation between the saturation of the wetting phase and the saturation of the mercury inlet under different mercury inlet pressures;
6) and drawing a nuclear magnetic capillary pressure curve according to the calculated mercury inlet saturation and the given mercury inlet pressure value, and acquiring the pore throat radius distribution of the reservoir layer according to the constructed nuclear magnetic capillary pressure curve.
The M mercury feeding pressures related to the step 1) are distributed according to the following modes:
in the formula:P c(i) Is as followsiThe individual mercury inlet pressure, in MPa.
The porosity and permeability curve of the reservoir in the step 2) can be directly obtained from the result of the inversion of the nuclear magnetic resonance logging, and can also be obtained by utilizing other conventional methods for calculation,T 2the geometric mean is obtained from the results of the inversion of the nmr log.
The method for calculating the reservoir flow unit index FZI in the step 3) comprises the following steps:
where FZI is the reservoir flow unit index,Kis reservoir permeability, mD;φis the reservoir porosity, decimal.
In the step 4), for three different types of reservoirs, respectively establishing a calculation formula of the saturation of the wetting phase by adopting the following method:
a) for class I reservoirs, the logarithm of the saturation of the wetting phase and the rock porosity are involvedφAndT 2geometric mean valueT 2LMThe functional relationship between the following:
in the formulaX iIs shown asiLog of wetting phase saturation at individual mercury intrusion pressure10(S w(i))，φIn order to be the porosity of the reservoir,T 2LMnuclear magnetic resonance of reservoirT 2A geometric mean;andall the coefficient matrixes are undetermined coefficient matrixes, and the numerical values of the coefficient matrixes are obtained by calibrating rock core experimental data;the matrix is a constant matrix to be determined, and the numerical value of the matrix is obtained by calibrating the rock core experimental data.
b) Log and rock of relative wetting phase saturation for type II reservoirsPorosity of stoneφAndT 2geometric mean valueT 2LMThe functional relationship between the following:
in the formulaX iIs shown asiLog of wetting phase saturation at individual mercury intrusion pressure10(S w(i))，φIn order to be the porosity of the reservoir,T 2LMnuclear magnetic resonance of reservoirT 2A geometric mean;the sum is an undetermined coefficient matrix, and the numerical value of the undetermined coefficient matrix is obtained by calibrating the rock core experimental data;the matrix is a constant matrix to be determined, and the numerical value of the matrix is obtained by calibrating the rock core experimental data.
c) For class III reservoirs, the logarithm of the saturation of the wetting phase and the rock porosity are involvedφAndT 2geometric mean valueT 2LMThe functional relationship between the following:
in the formulaX iIs shown asiLog of wetting phase saturation at individual mercury intrusion pressure10(S w(i))，φIn order to be the porosity of the reservoir,T 2LMnuclear magnetic resonance of reservoirT 2A geometric mean;andare all undetermined coefficientsThe matrix is obtained by calibrating the numerical values of the matrix by using the core experiment data;the matrix is a constant matrix to be determined, and the numerical value of the matrix is obtained by calibrating the rock core experimental data.
The step 4) of utilizing reservoir porosity and pore size for class I, class II and class III reservoirsT 2Calculation of geometric meanX iThen according toX iThe formula for calculating the saturation of the wetting phase under different mercury inlet pressures is as follows:
in the step 4), for three different types of reservoirs, a calculation method of the saturation of the wetting phase is established in the following mode respectively:
a) for class I reservoirs, only the mercury pressure is calculated when the NMR logging data is used to calculate the wetting phase saturationP c(i) Saturation of wetting phase of not less than 0.08MPa for mercury inlet pressureP c(i)<The saturation of the wetting phase in the portion of 0.08MPa is set equal to 100;
b) for class II reservoirs, only the feed mercury pressure is calculated when the NMR logging data is used to calculate the wetting phase saturationP c(i) Saturation of wetting phase of not less than 0.16MPa for mercury inlet pressureP c(i)<The saturation of the wetting phase in the portion of 0.16MPa is set equal to 100;
c) for class III reservoirs, only the mercury pressure is calculated when the NMR logging data is used to calculate the wetting phase saturationP c(i) Saturation of wetting phase of 1.28MPa or more for mercury inlet pressureP c(i)<The saturation of the wetting phase in the portion of 1.28MPa is set equal to 100.
In the step 5), the mercury inlet saturation under different mercury inlet pressures is calculated by adopting the following formula:
the method for acquiring the pore-throat radius distribution of the reservoir by utilizing the constructed nuclear magnetic capillary pressure curve in the step 6) is carried out according to the method described in the general high school "fifteen" planning teaching material oil layer physics "of the writings of Yangsheng and the like at page 209 and 233.
The invention has the beneficial effects that: on the basis of classifying the reservoirs according to FZI, a continuous nuclear magnetic capillary pressure curve is constructed by using nuclear magnetic resonance logging information, the pore throat radius distribution of the reservoirs is obtained according to the nuclear magnetic capillary pressure curve, and the purpose of continuously and quantitatively evaluating the pore structure of the reservoirs by using the nuclear magnetic resonance logging information can be achieved.
Drawings
The invention is further illustrated by the following figures and examples.
FIG. 1 is a flow chart of a nuclear magnetic capillary pressure curve construction method based on reservoir classification provided by the invention.
FIG. 2 is a schematic diagram of the pressure curve of a mercury pressing capillary tube of a total of 84 rock core samples of four domestic basins provided by the embodiment of the invention.
FIG. 3 is a J function curve diagram of a total of 84 core samples from four basins in China according to an embodiment of the present invention.
Fig. 4 is a graphical representation of a J-function curve for a class I core sample provided by an embodiment of the present disclosure.
Fig. 5 is a graphical representation of a J-function curve for a class II core sample provided by an embodiment of the present disclosure.
Fig. 6 is a graphical representation of a J-function curve for a class III core sample provided by an embodiment of the present disclosure.
Fig. 7 is a schematic diagram comparing a nuclear magnetic capillary pressure curve of a 4-block typical core sample configuration with an experimental mercury intrusion capillary pressure curve of a core provided in an embodiment of the present invention.
Fig. 8 is a graph showing a comparison effect between a nuclear magnetic capillary pressure curve constructed from measured nuclear magnetic resonance logging data by using the method according to the present invention and a reservoir pore throat radius distribution obtained by using the nuclear magnetic capillary pressure curve and a rock core mercury intrusion experiment result, according to an embodiment of the present invention.
Detailed Description
Theoretical analysis
Generally, for core samples in the same area and in the same batch for mercury intrusion tests, the mercury intrusion pressure applied in the mercury intrusion test process is the same. Therefore, the morphology of the capillary pressure curve is mainly controlled by the mercury feed saturation at different mercury feed pressures. Under the condition of applying the same mercury inlet pressure, for rocks with better pore structures, the mercury inlet amount pressed into the pore spaces of the rocks is more, and the corresponding mercury inlet saturation is higher; on the contrary, for the rock with poor pore structure, the mercury inlet amount pressed into the pore space of the rock is small, and the corresponding mercury inlet saturation is low. Therefore, only the mercury inlet saturation values under different mercury inlet pressures need to be calculated, and the capillary pressure curve can be constructed by combining the given mercury inlet pressure. In the following, a new method for constructing nuclear magnetic capillary pressure curves is theoretically derived by combining the analysis.
(1) Theory of J function
The J function was first proposed by Leverett in 1941 to average the capillary pressure curve, and the mathematical expression for the J function is:
（1）
in the formulaS wRepresents the wetting phase saturation,%.P c(S w) Representing capillary pressure, dyn/cm, corresponding to a given wetting phase saturation2；Represents the surface tension of the two-phase fluid, dyn/cm;represents the wetting contact angle (o）。KRepresents rock permeability, mD;φrepresents the rock porosity, decimal.Representing J function, dimensionless, commonly usedJ(S w) And (4) showing.
(2) SDR model
The SDR model is a model which is provided by Kenyon and the like of the research center of Schlumberger Doll and calculates the permeability of a reservoir layer by utilizing nuclear magnetic resonance logging, and the mathematical expression of the SDR model is as follows:
（2）
in the formulaC、mAndnthe parameters are SDR model parameters, and the numerical values of the parameters can be obtained through statistical regression of core data;T 2LMrepresentative NMR well loggingT 2Geometric mean, ms.
(3) Nuclear magnetism capillary pressure curve construction model combining J function and SDR model
If both sides of the formula (2) are divided by the porosity of the rockφAnd after taking out the square, obtaining:
（3）
substituting formula (3) into formula (1) to obtain:
（4）
SPEAsiaPacificicOil held in 9 months 2006&At the GasConferenceExhibition conference, an article by Wang et al, "assisted procedure of obtaining and utilizing tissue sample pressure-failure data interaction of rock core simulation" indicated that for core samples having the same J-function, at a given mercury inlet pressure, the wetting phase saturationS wAnd J (S w) The functions have a power functional relationship as shown in formula (5):
,i=1……M（5）
in the formulaS w(i) Represents the firstiPressure of capillaryP c(i) Lower wetting phase saturation,%;Mrepresenting the number of the mercury inlet pressure points set in the mercury injection experiment;a(i) Andb(i) Are model parameters, and the corresponding values are obtained by statistical regression of core experimental results.
Substituting formula (5) into formula (4) yields:
（6）
wherein,
if two sides of the formula (6) are logarithmized, obtaining
（7）
According to the relation between the saturation of the wetting phase and the saturation of the mercury entering, the calculation formula of the mercury entering saturation is obtained as follows:
（8）
equation (7) shows that for a rock with the same J-function, the wetting phase saturation is at a given mercury feed pressureS wPorosity with rockφAndT 2geometric mean valueT 2LMAnd (4) correlating. Therefore, only the saturation of the wetting phase at different mercury injection pressures needs to be establishedS w(i) Porosity of rockφAndT 2geometric mean valueT 2LMThe saturation of the wetting phase under different mercury inlet pressures can be calculated from the nuclear magnetic resonance logging data by the functional relation between the saturation of the wetting phase and the saturation of the mercury inlet under different mercury inlet pressures by using the formula (8). And finally, combining the given mercury inlet pressure and the calculated mercury inlet saturation to construct a nuclear magnetic capillary pressure curve.
Equation (5) indicates that equation (7) is true provided that all core samples have the same J function. In other words, when the core samples do not have the same J function, equation (5) will no longer hold, at which point the above-described method of constructing a nuclear magnetic capillary pressure curve will no longer hold. Therefore, the nuclear magnetic capillary pressure curve structural model shown in the formula (7) has certain limitations and does not have wide application value. In order to improve the wide applicability of the method, the invention provides a nuclear magnetic capillary pressure curve construction method based on reservoir classification.
The specific concepts and methods of the present invention are described below in terms of specific examples.
FIG. 2 is a mercury intrusion capillary pressure curve of 84 rock core samples collected from four basins in China, and FIG. 3 is a J function curve of the corresponding samples. The mercury injection pressure was applied to all samples for mercury intrusion experiments as follows:
P c(i)=0.005×2 i-1,i=1,2,…,13
in the formula:P c(i) To be applied firstiThe individual mercury inlet pressure, in MPa.
From the results shown in fig. 2 and 3, it can be seen that the pore structure types of all samples are completely different, and all 84 core samples also do not have the same J function, so the model for calculating the saturation of the wetting phase described in equation (7) is no longer applicable.
In order to improve the applicability of the method, the invention proposes to divide 84 core samples into three types by using FZI, and obtains J function curves of the three types of core samples, and the results are respectively shown in FIGS. 4 to 6. As can be seen from the J-function curve shapes of the three types of core samples shown in fig. 4 to 6, after the core samples are classified by using FZI, the same J-function is provided for each type of core sample, and the model described in equation (7) is applicable.
On the basis of the theoretical derivation and the applicable condition analysis, the invention provides a nuclear magnetic capillary pressure curve construction method based on reservoir classification by combining the actually measured results of a rock core sample mercury intrusion capillary pressure experiment and a nuclear magnetic resonance experiment.
Referring to fig. 1, a nuclear magnetic capillary pressure curve construction method based on reservoir classification includes the following steps:
1) determining 13 mercury inlet pressures according to the characteristics and the operation process of the mercury injection experiment;
2) obtaining actual measured nuclear magnetic resonance well logging by inverting measured dataT 2Spectrum and reservoir porosity, permeability andT 2a geometric mean curve;
3) calculating a flow unit index FZI reflecting the characteristic difference of the reservoir by using the porosity and permeability curves, and classifying the reservoir by using the FZI according to the following standards: class I reservoir: FZI is more than or equal to 0.22; class II reservoirs: FZI is more than or equal to 0.04 and less than 0.22; class III reservoirs: FZI < 0.04;
4) and respectively establishing the saturation of the wetting phase and the porosity of the rock under 13 mercury inlet pressures aiming at three different types of reservoirsT 2Calculating 13 wetting phase saturation values corresponding to the 13 mercury inlet pressures from the nuclear magnetic resonance logging data by utilizing the functional relationship among the geometric mean values;
5) converting the 13 saturation degrees of the wetting phase obtained by calculation into 13 saturation degrees of mercury entering according to the relation between the saturation degrees of the wetting phase and the saturation degrees of the mercury entering;
6) and drawing a nuclear magnetic capillary pressure curve according to the calculated 13 mercury inlet saturation degrees and the given 13 mercury inlet pressure values. And acquiring the pore throat radius distribution of the reservoir according to the constructed nuclear magnetic capillary pressure curve.
The 13 mercury feeding pressure values related to the step 1) are determined by adopting the following formula:
P c(i)=0.005×2 i-1,i=1,2,…13
in the formula:P c(i) To be applied firstiThe individual mercury inlet pressure, in MPa.
The porosity and permeability curve of the reservoir in the step 2) can be directly obtained from the result of the inversion of the nuclear magnetic resonance logging, and can also be obtained by utilizing other conventional methods for calculation,T 2the geometric mean is obtained from the results of the inversion of the nmr log.
The method for calculating the reservoir flow unit index FZI in the step 3) comprises the following steps:
FZI is reservoir flow unit index, K is reservoir permeability, mD; phi is reservoir porosity, decimal.
In the step 4), for different types of reservoirs, establishing logarithm of saturation of wetting phase and porosity sum of reservoirs under different mercury inlet pressures according to the derivation result shown in the formula (7)T 2Geometric mean valueT 2LMAnd calculating 13 wetting phase saturation values from the nuclear magnetic resonance logging data by utilizing the functional relationship, wherein the specific wetting phase saturation acquisition method comprises the following steps:
a) for class I reservoirs, the log of the wetting phase saturation and rock porosity are establishedφAndT 2geometric mean valueT 2LMThe functional relationship between the following:
in the formulaX iIs shown asiLog of wetting phase saturation at individual mercury intrusion pressure10(S w(i))，φIn order to be the porosity of the reservoir,T 2LMnuclear magnetic resonance of reservoirT 2A geometric mean;andall the coefficient matrixes are undetermined coefficient matrixes, and the numerical values of the coefficient matrixes are obtained by calibrating rock core experimental data;the matrix is a constant matrix to be determined, and the numerical value of the matrix is obtained by calibrating the rock core experimental data.
The determination method of the coefficient matrix and the constant matrix in the I-type reservoir wetting phase saturation calculation model comprises the following steps:
selecting core samples with FZI not less than 0.22, and simultaneously carrying out mercury intrusion and nuclear magnetic resonance experiments, wherein the nuclear magnetic porosity and the nuclear magnetic resonanceT 2Geometric mean valueT 2LMAs independent variables, then, according to the experimental data of the pressure of the mercury-pressing capillary, 13 mercury-entering saturation values are determined as dependent variables; and finally, respectively determining the numerical values of the coefficient matrix and the constant matrix by adopting a multivariate linear statistical regression method.
After calculating the logarithm of the wetting phase saturation, the wetting phase saturation was calculated for the 13 mercury intrusion pressure in the type I reservoir using the following equation.
b) For class II reservoirs, the log of the wetting phase saturation and rock porosity are establishedφAndT 2geometric mean valueT 2LMThe functional relationship between the following:
in the formulaX iIs shown asiLog of wetting phase saturation at individual mercury intrusion pressure10(S w(i))，φIn order to be the porosity of the reservoir,T 2LMnuclear magnetic resonance of reservoirT 2A geometric mean;andall the coefficient matrixes are undetermined coefficient matrixes, and the numerical values of the coefficient matrixes are obtained by calibrating rock core experimental data;the matrix is a constant matrix to be determined, and the numerical value of the matrix is obtained by calibrating the rock core experimental data.
The determination method of the coefficient matrix and the constant matrix in the II-type reservoir wetting phase saturation calculation model comprises the following steps:
selecting FZI of not less than 0.04<0.22 core sample, and carrying out mercury intrusion and NMR experiments simultaneously, first, the nuclear magnetic porosity andT 2geometric mean valueT 2LMAs independent variables, then, according to the experimental data of the pressure of the mercury-pressing capillary, 13 mercury-entering saturation values are determined as dependent variables; and finally, respectively determining the numerical values of the coefficient matrix and the constant matrix by adopting a multivariate linear statistical regression method.
After calculating the logarithm of the wetting phase saturation, the wetting phase saturation at 13 mercury inlet pressures for the class II reservoir was calculated using the following equation.
c) For class III reservoirs, the log of the wetting phase saturation and rock porosity are establishedφAndT 2geometric mean valueT 2LMThe functional relationship between the following:
in the formulaX iIs shown asiLog of wetting phase saturation at individual mercury intrusion pressure10(S w(i))，φIn order to be the porosity of the reservoir,T 2LMnuclear magnetic resonance of reservoirT 2A geometric mean;andall the coefficient matrixes are undetermined coefficient matrixes, and the numerical values of the coefficient matrixes are obtained by calibrating rock core experimental data;the matrix is a constant matrix to be determined, and the numerical value of the matrix is obtained by calibrating the rock core experimental data.
The determination method of the coefficient matrix and the constant matrix in the III-type reservoir wetting phase saturation calculation model comprises the following steps:
selection of FZI<0.04 core sample, and performing mercury intrusion and NMR experiments simultaneously, first, the nuclear magnetic porosity andT 2geometric mean valueT 2LMAs independent variables, then, according to the experimental data of the pressure of the mercury-pressing capillary, 13 mercury-entering saturation values are determined as dependent variables; and finally, respectively determining the numerical values of the coefficient matrix and the constant matrix by adopting a multivariate linear statistical regression method.
After calculating the logarithm of the wetting phase saturation, the wetting phase saturation was calculated for the 13 mercury intrusion pressure in the class III reservoir using the following equation.
Analysis of experimental data of mercury injection capillary pressure of the class I rock core sample in the step 5) shows that for the class I rock, when the applied mercury injection pressure is less than 0.08MPaExcept for very individual samples, mercury, which is nearly non-wetting, can be squeezed into the rock pore spaces, which are almost completely filled with the wetting phase fluid. Therefore, the wetting phase saturation for most core samples is equal to 100, and the morphology of this portion of the capillary pressure curve is of little significance for studying reservoir pore structure. Thus, for the type I core sample, only the mercury pressure was built inP c(i) Saturation of wetting phase of not less than 0.08MPa for mercury inlet pressureP c(i)<The saturation of the wetting phase in the portion of 0.08MPa is set equal to 100.
Analysis of experimental data of mercury injection capillary pressure of the class II core sample in the step 5) shows that for the class II rock, when the applied mercury injection pressure is less than 0.16MPa, almost non-wetting mercury can be squeezed into rock pore spaces except for the extremely individual samples, and the rock pore spaces are almost completely filled with the wetting phase fluid. Therefore, the wetting phase saturation for most core samples is equal to 100, and the morphology of this portion of the capillary pressure curve is of little significance for studying reservoir pore structure. Thus, for the type II core sample, only the mercury pressure build-up was performedP c(i) Saturation of wetting phase of not less than 0.16MPa for mercury inlet pressureP c(i)<The saturation of the wetting phase in the portion of 0.16MPa is set equal to 100.
Analysis of experimental data of mercury injection capillary pressure of the type III rock core sample in the step 5) shows that for the type III rock, when the applied mercury inlet pressure is less than 1.28MPa, mercury with little non-wettability can be squeezed into rock pore spaces except for very individual samples, and the rock pore spaces are almost completely filled with wetting phase fluid. Therefore, the wetting phase saturation for most core samples is equal to 100, and the morphology of this portion of the capillary pressure curve is of little significance for studying reservoir pore structure. Thus, for the class III core sample, only the mercury intrusion pressure was constructedP c(i) Saturation of wetting phase of 1.28MPa or more for mercury inlet pressureP c(i)<1.28MPaThe wetting phase saturation of that part is set equal to 100.
And 5) calculating the saturation of the wetting phase by using a following formula after calculating the saturation of the wetting phase by using nuclear magnetic resonance logging according to the correlation between the saturation of the wetting phase and the saturation of the mercury entering in the reservoir under 13 mercury entering pressures.
According to the nuclear magnetic capillary pressure curve construction method based on reservoir classification, 84 rock core samples drilled in four basins in China are processed, numerical values of a coefficient matrix and a constant matrix in a three-class reservoir wetting phase saturation calculation formula are calibrated respectively, and a model for continuously constructing a capillary pressure curve is obtained. And processing the actually measured nuclear magnetic resonance logging data by using the calibrated three types of reservoir nuclear magnetic capillary pressure curve structural models to obtain a continuously distributed nuclear magnetic capillary pressure curve, and converting to obtain the radius distribution of the pore throat of the reservoir. In order to quantitatively represent the reliability of the nuclear magnetic capillary pressure curve structural model, capillary pressure curves of 4 representative core samples are selected and compared with the nuclear magnetic capillary pressure curve constructed on the corresponding stratum depth.
Figure 7 lists 4 representative core mercury intrusion pressure curves versus constructed nuclear magnetic capillary pressure curves. The pore structure of the reservoirs represented by core samples No. 1 through No. 4 gradually worsened from good. As can be seen from the figure, for various types of rocks, the pressure curve of the nuclear magnetic capillary constructed by the method of the invention is well matched with the pressure curve of the mercury pressing capillary obtained by a rock core experiment, and the construction method of the pressure curve of the nuclear magnetic capillary is proved to be reliable.
FIG. 8 shows a nuclear magnetic capillary pressure curve constructed by the method of the present invention, and the capillary pressure curve obtained from reservoir pore throat radius distribution and core mercury intrusion experimentsAnd a comparison of pore throat radius distribution. The effect plot shown in figure 8 is divided into ten plots, the first of which includes the natural gamma curve (GR) and the well diameter Curve (CAL), primarily for identifying an effective sandstone reservoir; the second channel comprises a density logging (DEN) curve, a neutron logging (CNL) curve and an acoustic time difference logging (AC) curve, and is mainly used for calculating the porosity of the reservoir; the third trace is a deep lateral resistivity curve (RT) and a shallow lateral resistivity curve (RXO); the fourth track is a depth track, and the unit is m; fifth run nuclear magnetic resonance log including actual measurementsT 2Spectrum T2_ DIST; the sixth panel lists the comparison of the porosity curve obtained from the nmr log (TCMR) and the porosity of the core analysis (CPOR); the seventh step is to compare the Permeability (PERM) obtained from the nuclear magnetic resonance logging with the permeability (CPERM) of the core analysis, and as can be seen from the comparison results shown in the sixth and seventh steps, the porosity and permeability obtained by the nuclear magnetic resonance logging are basically consistent with the core analysis result, so that the obtained porosity and permeability are proved to be accurate, and the reliability of dividing the reservoir by calculating the FZI parameter by using the nuclear magnetic porosity and permeability is ensured; the eighth trace is an FZI curve calculated by utilizing nuclear magnetic porosity and permeability, which is mainly used for dividing a reservoir stratum; the ninth run is NMR logging using actual measurements according to the method of the inventionT 2Comparing a nuclear magnetic capillary pressure curve with a spectrum continuous structure with a rock core mercury-pressing capillary pressure curve, wherein a black curve is the nuclear magnetic capillary pressure curve which is continuously constructed by utilizing nuclear magnetic resonance logging information, for the convenience of curve display, the nuclear magnetic capillary pressure curve is accumulated to a state that the maximum mercury inlet pressure is 20.48MPa, and a discrete black dotted line is the rock core mercury-pressing capillary pressure curve; the tenth shows a comparison graph of the pore throat radius distribution of the reservoir layer converted by the nuclear magnetic capillary pressure curve constructed by the method of the invention and the pore throat radius distribution obtained by the mercury intrusion capillary pressure curve, wherein the discrete curve in the graph is the pore throat radius distribution obtained according to the rock core mercury intrusion capillary pressure curve. From the results shown in the ninth and tenth paragraphs, it can be seen that the pressure curve of the nuclear magnetic capillary constructed by the method of the present invention and the pore-throat radius distribution and distribution obtained by the method of the present inventionThe rock core mercury intrusion test results have better consistency. This shows that NMR logging can be performed using the method of the present inventionT 2The spectra are continuously converted to nuclear magnetic capillary pressure curves to obtain an accurate reservoir pore throat radius distribution.
Finally, it should be noted that: it should be understood that the above examples are only for clearly illustrating the present invention and are not intended to limit the embodiments. Other variations and modifications will be apparent to persons skilled in the art in light of the above description. And are neither required nor exhaustive of all embodiments. And obvious variations or modifications therefrom are intended to be within the scope of the invention.
Claims (10)
1. A nuclear magnetism capillary pressure curve construction method based on reservoir classification is characterized by comprising the following steps: according to the nuclear magnetic resonance logging data and the limited capillary pressure data, the porosity, permeability and permeability of the reservoir are obtained by inverting the nuclear magnetic resonance logging dataT 2A geometric mean curve; calculating a flow unit index FZI reflecting reservoir layer differences by using porosity and permeability curves, dividing the reservoir layers into three types by using the FZI, and respectively establishing wetting phase saturation and nuclear magnetic resonance porosity under different mercury inlet pressures for each type of reservoir layersφAndT 2geometric mean valueT 2LMCalculating the saturation of the wetting phase under different mercury inlet pressures according to the obtained functional relation, and converting the saturation to obtain the mercury inlet saturation; constructing a nuclear magnetism capillary pressure curve according to the calculated mercury inlet saturation and the corresponding mercury inlet pressure; and according to the nuclear magnetic capillary pressure curve, acquiring pore throat radius distribution, and realizing the purpose of continuously and quantitatively evaluating the pore structure of the reservoir.
2. A method for constructing a nuclear magnetic capillary pressure curve based on reservoir classification, the method comprising the steps of:
1) determining M mercury inlet pressures on the basis of analyzing the characteristics of a rock core mercury intrusion experiment and the operation process;
2) collecting reservoir data by using a nuclear magnetic resonance logging instrument, and inverting the collected data to obtain nuclear magnetic resonance loggingT 2Spectrum and reservoir porosity, permeability andT 2a geometric mean curve;
3) calculating a flow unit index FZI reflecting the characteristic difference of the reservoir by using the porosity and permeability curves, and classifying the reservoir by using the FZI according to the following standards: class I reservoir: FZI is more than or equal to 0.22; class II reservoirs: FZI is more than or equal to 0.04 and less than 0.22; class III reservoirs: FZI < 0.04;
4) aiming at three different types of reservoirs, the wetting phase saturation and the rock porosity sum under M different mercury inlet pressures are respectively establishedT 2Calculating M wetting phase saturation values corresponding to M mercury inlet pressures from nuclear magnetic resonance logging data by utilizing the functional relation among the geometric mean values;
5) converting the calculated saturation of the wetting phase into saturation of the mercury inlet according to the relation between the saturation of the wetting phase and the saturation of the mercury inlet under different mercury inlet pressures;
6) and drawing a nuclear magnetic capillary pressure curve according to the calculated mercury inlet saturation and the given mercury inlet pressure value, and acquiring the pore throat radius distribution of the reservoir according to the constructed nuclear magnetic capillary pressure curve.
3. A method of constructing a nuclear magnetic capillary pressure curve based on reservoir classification as claimed in claim 1 or 2, wherein: the M mercury feeding pressures related to the step 1) are distributed according to the following modes:
in the formula:P c(i) Is as followsiThe individual mercury inlet pressure, in MPa.
4. A method of constructing a nuclear magnetic capillary pressure curve based on reservoir classification as claimed in claim 1 or 2, wherein: the porosity and permeability curve of the reservoir in the step 2) can be directly obtained from the result of the inversion of the nuclear magnetic resonance logging, and can also be obtained by utilizing other conventional methods for calculation,T 2the geometric mean is obtained from the results of the inversion of the nmr log.
5. A method of constructing a nuclear magnetic capillary pressure curve based on reservoir classification as claimed in claim 1 or 2, wherein: the method for calculating the reservoir flow unit index FZI in the step 3) comprises the following steps:
where FZI is the reservoir flow unit index,Kis reservoir permeability, mD;φis the reservoir porosity, decimal.
6. A method of constructing a nuclear magnetic capillary pressure curve based on reservoir classification as claimed in claim 1 or 2, wherein: in the step 4), for three different types of reservoirs, a calculation model of the saturation of the wetting phase is established by adopting the following formula:
a) for class I storageStratification, logarithm of saturation of the wetting phase involved and rock porosityφAndT 2geometric mean valueT 2LMThe functional relationship between the following:
in the formulaX iIs shown asiLog of wetting phase saturation at individual mercury intrusion pressure10(S w(i))，φIn order to be the porosity of the reservoir,T 2LMnuclear magnetic resonance of reservoirT 2A geometric mean;andall the coefficient matrixes are undetermined coefficient matrixes, and the numerical values of the coefficient matrixes are obtained by calibrating rock core experimental data;the constant matrix is undetermined, and the numerical value of the constant matrix is obtained by calibrating the rock core experimental data;
b) for class II reservoirs, the logarithm of the saturation of the wetting phase and the rock porosity are involvedφAndT 2geometric mean valueT 2LMThe functional relationship between the following:
in the formulaX iIs shown asiLog of wetting phase saturation at individual mercury intrusion pressure10(S w(i))，φIn order to be the porosity of the reservoir,T 2LMnuclear magnetic resonance of reservoirT 2A geometric mean;andall the coefficient matrixes are undetermined coefficient matrixes, and the numerical values of the coefficient matrixes are obtained by calibrating rock core experimental data;the constant matrix is undetermined, and the numerical value of the constant matrix is obtained by calibrating the rock core experimental data;
c) for class III reservoirs, the logarithm of the saturation of the wetting phase and the rock porosity are involvedφAndT 2geometric mean valueT 2LMThe functional relationship between the following:
in the formulaX iIs shown asiLog of wetting phase saturation at individual mercury intrusion pressure10(S w(i))，φIn order to be the porosity of the reservoir,T 2LMnuclear magnetic resonance of reservoirT 2A geometric mean;andall the coefficient matrixes are undetermined coefficient matrixes, and the numerical values of the coefficient matrixes are obtained by calibrating rock core experimental data;the matrix is a constant matrix to be determined, and the numerical value of the matrix is obtained by calibrating the rock core experimental data.
7. A method of constructing a nuclear magnetic capillary pressure curve based on reservoir classification as claimed in claim 1 or 2, wherein: the step 4) of utilizing reservoir pores for class I, class II and class III reservoirsDegree of clearance andT 2calculation of geometric meanX iThen according toX iThe formula for calculating the saturation of the wetting phase under different mercury inlet pressures is as follows:
。
8. a method of constructing a nuclear magnetic capillary pressure curve based on reservoir classification as claimed in claim 1 or 2, wherein: in the step 4), for three types of reservoirs, establishing a mercury-entering saturation degree calculation method in the following way:
a) for class I reservoirs, only the mercury pressure is calculated when the NMR logging data is used to calculate the wetting phase saturationP c(i) Saturation of wetting phase of not less than 0.08MPa for mercury inlet pressureP c(i)<The saturation of the wetting phase in the portion of 0.08MPa is set equal to 100;
b) for class II reservoirs, only the feed mercury pressure is calculated when the NMR logging data is used to calculate the wetting phase saturationP c(i) Saturation of wetting phase of not less than 0.16MPa for mercury inlet pressureP c(i)<The saturation of the wetting phase in the portion of 0.16MPa is set equal to 100;
c) for class III reservoirs, only the mercury pressure is calculated when the NMR logging data is used to calculate the wetting phase saturationP c(i) Saturation of wetting phase of 1.28MPa or more for mercury inlet pressureP c(i)<The saturation of the wetting phase in the portion of 1.28MPa is set equal to 100.
9. A method of constructing a nuclear magnetic capillary pressure curve based on reservoir classification as claimed in claim 1 or 2, wherein: the calculation formula of the mercury inlet saturation under different mercury inlet pressures in the step 5) is as follows:
。
10. a method of constructing a nuclear magnetic capillary pressure curve based on reservoir classification as claimed in claim 1 or 2, wherein: the method for acquiring the pore-throat radius distribution of the reservoir by utilizing the constructed nuclear magnetic capillary pressure curve in the step 6) is carried out according to the method described in the general high school "fifteen" planning teaching material oil layer physics "of the writings of Yangsheng and the like at page 209 and 233.
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Application publication date: 20160224 |