CN114046145A - Reservoir fluid identification and saturation determination method and device - Google Patents

Reservoir fluid identification and saturation determination method and device Download PDF

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CN114046145A
CN114046145A CN202111424638.4A CN202111424638A CN114046145A CN 114046145 A CN114046145 A CN 114046145A CN 202111424638 A CN202111424638 A CN 202111424638A CN 114046145 A CN114046145 A CN 114046145A
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谢然红
王帅
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China University of Petroleum Beijing
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Abstract

The application discloses a reservoir fluid identification and saturation determination method and device, wherein the method comprises the following steps: calculating apparent formation water resistivity of the reservoir; fitting the distribution of the evolution of the apparent formation water resistivity by using a distribution function to obtain a water spectrum; identifying the fluid type of the reservoir according to the shape of the water spectrum; and (4) integrating the mean value, the standard deviation and the end points of the water spectrum to determine the saturation of the reservoir. Therefore, the reservoir fluid type is identified by using the water spectrum result of the distribution function, and the reservoir saturation is determined by using the water spectrum characteristic parameter, so that the operation is simple, and the accuracy of the data result is high.

Description

Reservoir fluid identification and saturation determination method and device
Technical Field
The invention relates to the field of oil and gas exploration and development, in particular to a reservoir fluid identification and saturation determination method and device.
Background
Although new logging methods such as nuclear magnetic resonance logging, array acoustic logging, dielectric logging and the like can provide certain help for solving the problems, most wells, especially old wells, lack the novel logging means, and the wells usually only have conventional logging data, so that the development of the low-contrast reservoir fluid identification and saturation determination method based on conventional logging has important significance for the exploration and development of the concealed oil and gas reservoirs.
At present, the Archie's formula lays the foundation for calculating reservoir saturation by using resistivity. Subsequently, the additional conductivity phenomenon of the argillaceous sandstone clay is discovered, and based on the phenomenon, scholars propose various ways to calculate the saturation of the argillaceous sandstone reservoir, wherein the most popular ways are a double water model, a Waxman-Smith model, a Simandoux formula, an Indonesia formula and the like. However, the results obtained by the methods are easy to have local maximums which do not accord with the physical law, and the accuracy is low.
Disclosure of Invention
In view of this, the present invention provides a reservoir fluid identification and saturation determination method and device, which can improve the accuracy of data results and are simple to operate. The specific scheme is as follows:
a reservoir fluid identification and saturation determination method, comprising:
calculating apparent formation water resistivity of the reservoir;
fitting the evolution distribution of the apparent formation water resistivity by using a distribution function to obtain a water spectrum;
identifying a fluid type of the reservoir from the shape of the water spectrum;
and integrating the mean value, the standard deviation and the end points of the water spectrum to determine the saturation of the reservoir.
Preferably, in the method for identifying reservoir fluids and determining saturation provided by the embodiment of the present invention, calculating apparent formation water resistivity of the reservoir includes:
and calculating the apparent formation water resistivity of the reservoir by using the deep lateral resistivity or the deep induction resistivity of the reservoir and the porosity and the argillaceous content of the reservoir.
Preferably, in the reservoir fluid identification and saturation determination method provided by the embodiment of the present invention, the first formula for calculating the apparent formation water resistivity is as follows:
Figure BDA0003377792860000021
wherein R iswaIs the apparent formation water resistivity, RtIs the deep lateral resistivity or deep induced resistivity, phi is the porosity, m is the cementation index, e is the natural constant, VshIs the argillaceous content.
Preferably, in the method for reservoir fluid identification and saturation determination provided by the embodiment of the present invention, fitting the distribution of the evolution of apparent formation water resistivity by using a distribution function includes:
fitting the distribution of the evolution of the apparent formation water resistivity by using a Gaussian distribution function; the second formula of the Gaussian distribution function satisfied by the evolution of the apparent formation water resistivity is as follows:
Figure BDA0003377792860000022
wherein x is the evolution of the apparent formation water resistivity
Figure BDA0003377792860000023
f (x) is probability density, mu is
Figure BDA0003377792860000024
A mean value of
Figure BDA0003377792860000025
Standard deviation of (2).
Preferably, in the above method for identifying reservoir fluids and determining saturation provided by the embodiment of the present invention, identifying the fluid type of the reservoir according to the shape of the water spectrum includes:
if the shape of the water spectrum is wide and flat, identifying that the reservoir contains oil and gas;
if the shape of the water spectrum is narrow and sharp, only water in the reservoir is identified.
Preferably, in the reservoir fluid identification and saturation determination method provided by the embodiment of the present invention, the end points of the water spectrum are the minimum value and the maximum value of the evolution of the apparent formation water resistivity.
Preferably, in the reservoir fluid identification and saturation determination method provided by the embodiment of the present invention, a standard deviation of the water spectrum of the oil-water layer is greater than a standard deviation of the water spectrum of the water layer.
The embodiment of the invention also provides a reservoir fluid identification and saturation determination device, which comprises:
the water resistivity calculation module is used for calculating the apparent formation water resistivity of the reservoir;
the water spectrum fitting module is used for fitting the distribution of the evolution of the apparent formation water resistivity by using a distribution function to obtain a water spectrum;
the fluid identification module is used for identifying the fluid type of the reservoir according to the shape of the water spectrum;
and the saturation determination module is used for integrating the mean value, the standard deviation and the end points of the water spectrum to determine the saturation of the reservoir.
Preferably, in the above reservoir fluid identification and saturation determination apparatus provided in the embodiment of the present invention, the water resistivity calculation module is specifically configured to calculate apparent formation water resistivity of the reservoir by using deep lateral resistivity or deep induced resistivity of the reservoir, and by using porosity and shale content of the reservoir.
Preferably, in the above reservoir fluid identification and saturation determination apparatus provided in the embodiment of the present invention, the fluid identification module is specifically configured to identify that the reservoir contains hydrocarbons if the shape of the water spectrum is wide and flat; if the shape of the water spectrum is narrow and sharp, only water in the reservoir is identified.
According to the technical scheme, the reservoir fluid identification and saturation determination method provided by the invention comprises the following steps: calculating apparent formation water resistivity of the reservoir; fitting the distribution of the evolution of the apparent formation water resistivity by using a distribution function to obtain a water spectrum; identifying the fluid type of the reservoir according to the shape of the water spectrum; and (4) integrating the mean value, the standard deviation and the end points of the water spectrum to determine the fluid saturation of the reservoir.
The invention can calculate the apparent formation water resistivity, obtain the water spectrum by combining the distribution function to finish the reservoir fluid identification, and determine the reservoir fluid saturation by combining the mean value, the standard deviation and the end point of the water spectrum, thus identifying the reservoir fluid type by using the water spectrum result of the distribution function, and determining the reservoir fluid saturation by using the water spectrum characteristic parameters, the operation is simple, and the data result accuracy is high.
In addition, the invention also provides a corresponding device for the reservoir fluid identification and saturation determination method, so that the method has higher practicability and has corresponding advantages.
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In order to more clearly illustrate the embodiments of the present invention or technical solutions in related arts, the drawings used in the description of the embodiments or related arts will be briefly introduced below, it is obvious that the drawings in the following description are only embodiments of the present invention, and for those skilled in the art, other drawings can be obtained according to the provided drawings without creative efforts.
FIG. 1 is a flow chart of a reservoir fluid identification and saturation determination method provided by an embodiment of the invention;
FIG. 2 is a numerical simulation of apparent formation water resistivity using a prior art Indonesia formula;
FIG. 3 is a numerical simulation of apparent formation water resistivity as simulated using the method provided by embodiments of the present invention;
FIG. 4 is a graph comparing apparent formation water resistivity obtained using FIGS. 2 and 3 with actual well data;
FIG. 5 is a schematic representation of a reservoir water profile provided by an embodiment of the present invention;
FIG. 6 is a schematic diagram of water spectrum parameters provided by an embodiment of the present invention;
FIG. 7 is a schematic illustration of the correlation between water saturation and actual water saturation provided by an embodiment of the present invention;
FIG. 8 is a schematic diagram of the root mean square error of the simulation results provided by the embodiment of the present invention;
FIG. 9 is a diagram illustrating the effect of practical application provided by the embodiment of the present invention;
fig. 10 is a schematic structural diagram of a reservoir fluid identification and saturation determination apparatus according to an embodiment of the present invention.
Detailed Description
The technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the drawings in the embodiments of the present invention, and it is obvious that the described embodiments are only a part of the embodiments of the present invention, and not all of the embodiments. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present invention.
The invention provides a reservoir fluid identification and saturation determination method, as shown in fig. 1, comprising the following steps:
s101, calculating apparent formation water resistivity of a reservoir;
s102, fitting the evolution distribution of the apparent formation water resistivity by using a distribution function to obtain a water spectrum;
it is to be noted that the apparent formation water resistivity R is assumedwaIs opened
Figure BDA0003377792860000041
Subject to a distribution function, based on this assumption, fitting with the distribution function
Figure BDA0003377792860000042
The obtained functional distribution result can be called as a water spectrum.
S103, identifying the fluid type of the reservoir according to the shape of the water spectrum;
s104, integrating the mean value, the standard deviation and the end point of the water spectrum, and determining the saturation of the reservoir;
according to the reservoir fluid identification and saturation determination method provided by the embodiment of the invention, apparent formation water resistivity can be obtained through calculation, reservoir fluid identification is completed by combining a distribution function to obtain a water spectrum, and reservoir saturation is determined by integrating the mean value, standard deviation and end point of the water spectrum, so that the reservoir fluid type is identified by using the water spectrum result of the distribution function, and the reservoir saturation is determined by using the water spectrum characteristic parameters, the operation is simple, and the accuracy of the data result is high.
Further, in a specific implementation, in the reservoir fluid identification and saturation determination method provided in the embodiment of the present invention, the step S101 of calculating the apparent formation water resistivity of the reservoir may specifically include: and calculating the apparent formation water resistivity of the reservoir by using the deep lateral or deep induction resistivity, the porosity and the argillaceous content of the reservoir.
Specifically, the apparent formation water resistivity may be calculated using a first formula:
Figure BDA0003377792860000051
wherein R iswaIn view of formation water resistivity, RtIs the deep lateral or deep induced resistivity, phi is the porosity, m is the cementation index, e is the natural constant, VshIs the argillaceous content.
It should be noted that, the calculation result in the past may have a maximum value that does not conform to the physical law, and the value may even be infinite, but the present invention can overcome the defects of the calculation method of the apparent formation water resistivity by the above calculation method, and the obtained apparent formation water resistivity does not have a maximum value that does not conform to the physical law.
In specific implementation, in the method for reservoir fluid identification and saturation determination provided by the embodiment of the present invention, the step S102 of fitting the distribution of the evolution of the apparent formation water resistivity by using a distribution function includes: and fitting the distribution of the evolution of the apparent formation water resistivity by using a Gaussian distribution function. That is, the distribution function may be a gaussian distribution function, but other distribution functions are also possible.
In particular, the evolution of the apparent formation water resistivity
Figure BDA0003377792860000052
The following gaussian distribution function can be satisfied:
Figure BDA0003377792860000053
wherein x is the evolution of apparent formation water resistivity
Figure BDA0003377792860000054
f (x) is probability density, mu is
Figure BDA0003377792860000055
A mean value of
Figure BDA0003377792860000056
Standard deviation of (2).
In specific implementation, in the method for identifying reservoir fluids and determining saturation provided by the embodiment of the present invention, the step S103 identifies the fluid type of the reservoir according to the shape of the water spectrum, and specifically may include: if the shape of the water spectrum is wide and gentle, identifying that the reservoir contains oil gas; if the shape of the water spectrum is narrow and sharp, only water in the reservoir is identified.
In specific implementation, in the reservoir fluid identification and saturation determination method provided by the embodiment of the invention, the end point of the water spectrum may be the evolution of the apparent formation water resistivity
Figure BDA0003377792860000057
Minimum and maximum values of.
Specifically, in performing step S104, the saturation of the reservoir may be calculated by linear regression using four parameters of the mean, the standard deviation, the left end point, and the right end point of the water spectrum, which is referred to as a "four-parameter" method. The specific calculation formula is as follows:
Figure BDA0003377792860000061
wherein S isoIn order to obtain the degree of saturation of the oil,
Figure BDA0003377792860000062
is the value of the left end of the water spectrum (i.e. the value of
Figure BDA0003377792860000063
The minimum value of (d),
Figure BDA0003377792860000064
is the value of the right end of the water spectrum (i.e. the value of
Figure BDA0003377792860000065
Maximum of (d), μ is the average of the water spectra (i.e., the mean of the water spectra)
Figure BDA0003377792860000066
Mean of (d)), σ is the standard deviation of the water spectrum (i.e., σ is the standard deviation of the water spectrum
Figure BDA0003377792860000067
Standard deviation of) the coefficients a, b, c, d, e may be determined from the experimental results of the core in the study area to meet the actual conditions of the area.
The following further explains actual data processing of the numerical simulation and low-contrast tight sandstone reservoir with respect to the results obtained by the reservoir fluid identification and saturation determination method provided by the embodiment of the present invention:
fig. 2 and 3 show the results of simulation calculation of apparent formation water resistivity, fig. 2 is the result of simulation using the Indonesia formula, and fig. 3 is the result of calculation using the method provided by the present invention. As can be seen from the figure, the apparent formation water resistivity R derived from the Indonesia formula is higher than 20% when the argillaceous content is higher thanwaMaxima that do not comply with the physical laws may occur and are no longer applicable, and the method provided by the present invention overcomes this problem.
FIG. 4 shows a comparison of the two methods in processing actual well data. Rwa _ Indonesia in FIG. 4 is the result of a calculation using the Indonesia formula (see the fourth right dashed line in the figure); rwa _ New is the result calculated by the method provided by the present invention (see the left solid line of the fourth trace). Rwa _ Indonesia shows a number of maxima that do not follow the physical laws, which is not the case with Rwa _ New.
Fig. 5 and 6 show the difference between the water spectra of the oil-water layer and the water layer, the solid line in fig. 5 represents the water spectrum of the water layer, the dotted line represents the water spectrum of the oil-water layer, the abscissa in fig. 6 is the mean value of the water spectra, the ordinate is the standard deviation of the water spectra, the dots represent the oil-water layer, and the triangles represent the water layer. It can be seen that the water spectrum standard deviation of the oil-water layer is greater than that of the water layer.
In fig. 7, the abscissa represents the number of simulations, and the ordinate represents the determination coefficients for calculating the water saturation and the actual water saturation; the top line represents the simulation results of the four-parameter method of the present invention (mean, standard deviation, left end, right end), the middle line represents the simulation results of the two-parameter method (mean, standard deviation), and the bottom line represents the simulation results of the Indonesia formula. Simulation results show that the four-parameter method is superior to the two-parameter method, and the two-parameter method is superior to the Indonesia formula.
The ordinate in fig. 8 represents the root mean square error for each simulation. The bottom line represents the simulation results of the four parameter method of the present invention, the middle line represents the simulation results of the two parameter method, and the top line represents the simulation results of the Indonesia formula. Simulation results show that the four-parameter method is superior to the two-parameter method, and the two-parameter method is superior to the Indonesia formula.
In fig. 9, the abscissa represents calculated saturation data, and the ordinate represents core experimental saturation data, i.e., the average value of the core saturations belonging to the same reservoir. Triangles represent the results calculated by the Indonesia formula, diamonds represent the results calculated by the four-parameter method of the present invention, and squares represent the results calculated by the two-parameter method. It can be seen that the calculation result of the four-parameter method is optimal, and the determination coefficient is 0.98.
Based on the same inventive concept, the embodiment of the invention also provides a reservoir fluid identification and saturation determination device, and as the principle of solving the problem of the device is similar to that of the reservoir fluid identification and saturation determination method, the implementation of the device can refer to the implementation of the reservoir fluid identification and saturation determination method, and repeated parts are not repeated.
In specific implementation, the reservoir fluid identification and saturation determination apparatus provided in the embodiment of the present invention, as shown in fig. 10, specifically includes:
the water resistivity calculation module 11 is used for calculating the apparent formation water resistivity of the reservoir;
the water spectrum fitting module 12 is used for fitting the distribution of the evolution of the apparent formation water resistivity by using the distribution function to obtain a water spectrum;
a fluid identification module 13 for identifying the fluid type of the reservoir according to the shape of the water spectrum;
and the saturation determining module 14 is used for determining the saturation of the reservoir by integrating the mean value, the standard deviation and the end point of the water spectrum.
In the reservoir fluid identification and saturation determination device provided by the embodiment of the invention, the apparent formation water resistivity can be obtained through the interaction of the four modules, the reservoir fluid identification can be completed by obtaining the water spectrum by combining the distribution function, and the reservoir saturation can be determined by integrating the mean value, the standard deviation and the end point of the water spectrum, so that the reservoir fluid type can be identified by using the water spectrum result of the distribution function, and the reservoir saturation can be determined by using the water spectrum characteristic parameters, the operation is simple, and the accuracy of the data result is high.
Further, in the implementation, in the reservoir fluid identification and saturation determination apparatus provided in the embodiment of the present invention, the water resistivity calculation module 11 may be specifically configured to calculate the apparent formation water resistivity of the reservoir by using the deep lateral or deep induced resistivity, the porosity, and the shale content of the reservoir.
Further, in the implementation, in the reservoir fluid identification and saturation determination apparatus provided in the embodiment of the present invention, the fluid identification module 13 may be specifically configured to identify that the reservoir contains oil and gas if the shape of the water spectrum is wide and flat; if the shape of the water spectrum is narrow and sharp, only water in the reservoir is identified.
For more specific working processes of the modules, reference may be made to corresponding contents disclosed in the foregoing embodiments, and details are not repeated here.
The embodiments are described in a progressive manner, each embodiment focuses on differences from other embodiments, and the same or similar parts among the embodiments are referred to each other. The device disclosed by the embodiment corresponds to the method disclosed by the embodiment, so that the description is simple, and the relevant points can be referred to the method part for description.
Those of skill would further appreciate that the various illustrative elements and algorithm steps described in connection with the embodiments disclosed herein may be implemented as electronic hardware, computer software, or combinations of both, and that the various illustrative components and steps have been described above generally in terms of their functionality in order to clearly illustrate this interchangeability of hardware and software. Whether such functionality is implemented as hardware or software depends upon the particular application and design constraints imposed on the implementation. Skilled artisans may implement the described functionality in varying ways for each particular application, but such implementation decisions should not be interpreted as causing a departure from the scope of the present application.
The steps of a method or algorithm described in connection with the embodiments disclosed herein may be embodied directly in hardware, in a software module executed by a processor, or in a combination of the two. A software module may reside in Random Access Memory (RAM), memory, Read Only Memory (ROM), electrically programmable ROM, electrically erasable programmable ROM, registers, hard disk, a removable disk, a CD-ROM, or any other form of storage medium known in the art.
To sum up, the reservoir fluid identification and saturation determination method provided by the embodiment of the invention comprises the following steps: calculating apparent formation water resistivity of the reservoir; fitting the distribution of the evolution of the apparent formation water resistivity by using a distribution function to obtain a water spectrum; identifying the fluid type of the reservoir according to the shape of the water spectrum; and (4) integrating the mean value, the standard deviation and the end points of the water spectrum to determine the saturation of the reservoir. Therefore, the reservoir fluid type is identified by using the water spectrum result of the distribution function, and the reservoir saturation is determined by using the water spectrum characteristic parameter, so that the operation is simple, and the accuracy of the data result is high. In addition, the invention also provides a corresponding device for the reservoir fluid identification and saturation determination method, so that the method has higher practicability and has corresponding advantages.
Finally, it should also be noted that, herein, relational terms such as first and second, and the like may be used solely to distinguish one entity or action from another entity or action without necessarily requiring or implying any actual such relationship or order between such entities or actions. Also, the terms "comprises," "comprising," or any other variation thereof, are intended to cover a non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements does not include only those elements but may include other elements not expressly listed or inherent to such process, method, article, or apparatus. Without further limitation, an element defined by the phrase "comprising an … …" does not exclude the presence of other identical elements in a process, method, article, or apparatus that comprises the element.
The reservoir fluid identification and saturation determination method and device provided by the invention are described in detail above, and the principle and the implementation of the invention are explained in the present document by applying specific examples, and the description of the above examples is only used to help understanding the method and the core idea of the invention; meanwhile, for a person skilled in the art, according to the idea of the present invention, there may be variations in the specific embodiments and the application scope, and in summary, the content of the present specification should not be construed as a limitation to the present invention.

Claims (10)

1. A method for reservoir fluid identification and saturation determination, comprising:
calculating apparent formation water resistivity of the reservoir;
fitting the evolution distribution of the apparent formation water resistivity by using a distribution function to obtain a water spectrum;
identifying a fluid type of the reservoir from the shape of the water spectrum;
and integrating the mean value, the standard deviation and the end points of the water spectrum to determine the saturation of the reservoir.
2. The reservoir fluid identification and saturation determination method of claim 1, wherein calculating apparent formation water resistivity of the reservoir comprises:
and calculating the apparent formation water resistivity of the reservoir by using the deep lateral resistivity or the deep induction resistivity of the reservoir and the porosity and the argillaceous content of the reservoir.
3. The reservoir fluid identification and saturation determination method of claim 2, wherein the first formula for calculating the apparent formation water resistivity is:
Figure FDA0003377792850000011
wherein R iswaIs the apparent formation water resistivity, RtIs the deep lateral resistivity or deep induced resistivity, phi is the porosity, m is the cementation index, e is the natural constant, VshIs the argillaceous content.
4. The method of reservoir fluid identification and saturation determination of claim 3, wherein fitting the distribution of the evolution of apparent formation water resistivity with a distribution function comprises:
fitting the distribution of the evolution of the apparent formation water resistivity by using a Gaussian distribution function; the second formula of the Gaussian distribution function satisfied by the evolution of the apparent formation water resistivity is as follows:
Figure FDA0003377792850000012
wherein x is the evolution of the apparent formation water resistivity
Figure FDA0003377792850000013
f (x) is probability density, mu is
Figure FDA0003377792850000014
A mean value of
Figure FDA0003377792850000015
Standard deviation of (2).
5. The reservoir fluid identification and saturation determination method of claim 4, wherein identifying the fluid type of the reservoir from the shape of the water spectrum comprises:
if the shape of the water spectrum is wide and flat, identifying that the reservoir contains oil and gas;
if the shape of the water spectrum is narrow and sharp, only water in the reservoir is identified.
6. The reservoir fluid identification and saturation determination method of claim 5, wherein the end points of the water spectrum are the minimum and maximum values of the evolution of the apparent formation water resistivity.
7. The reservoir fluid identification and saturation determination method of claim 6, wherein a standard deviation of the water spectra of oil-water layer is greater than a standard deviation of the water spectra of water layer.
8. A reservoir fluid identification and saturation determination apparatus, comprising:
the water resistivity calculation module is used for calculating the apparent formation water resistivity of the reservoir;
the water spectrum fitting module is used for fitting the distribution of the evolution of the apparent formation water resistivity by using a distribution function to obtain a water spectrum;
the fluid identification module is used for identifying the fluid type of the reservoir according to the shape of the water spectrum;
and the saturation determination module is used for integrating the mean value, the standard deviation and the end points of the water spectrum to determine the saturation of the reservoir fluid.
9. Reservoir fluid identification and saturation determination apparatus according to claim 8, wherein said water resistivity calculation module is specifically configured to calculate apparent formation water resistivity of the reservoir using deep lateral resistivity or deep induced resistivity of the reservoir, and using porosity, shale content of the reservoir.
10. Reservoir fluid identification and saturation determination apparatus as claimed in claim 9, wherein said fluid identification module is specifically configured to identify that hydrocarbons are contained in said reservoir if said water spectrum is wide and flat in shape; if the shape of the water spectrum is narrow and sharp, only water in the reservoir is identified.
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