CN111101923A - Method and device for calculating fracture laminar flow index and storage medium - Google Patents
Method and device for calculating fracture laminar flow index and storage medium Download PDFInfo
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Abstract
The invention provides a method, a device and a storage medium for calculating a fracture laminar flow index, wherein a well wall conductivity image of a target well is obtained, the well wall conductivity image is segmented, a well wall target sub-image of the target well is obtained, the well wall target sub-image comprises a fracture target, further, a geometric parameter of the fracture target is obtained according to the well wall target sub-image, then, the fracture laminar flow index of the well wall conductivity image corresponding to the target well is obtained according to the geometric parameter of the fracture target and the area of the well wall conductivity image, and the fracture laminar flow index is used for expressing the flowability of fluid in a fractured reservoir. The method comprises the steps of obtaining a borehole wall conductivity image of a target layer by adopting an electrical imaging logging technology, obtaining a fracture laminar flow index of a corresponding well section, and measuring the flowability of a fluid in fractured compact sandstone by using the fracture laminar flow index.
Description
Technical Field
The invention relates to the technical field of well logging, in particular to a method and a device for calculating a fracture laminar flow index and a storage medium.
Background
With the development and utilization of resources such as oil, natural gas and the like, the oil and gas reserves in the conventional porous reservoir are gradually reduced, and the development difficulty is also gradually increased, so that the exploration direction is gradually changed from the conventional porous reservoir to other types of reservoirs, such as a fractured compact sandstone reservoir. In a fractured compact sandstone reservoir, oil and natural gas mainly flow in fractures, and the fractures are also main channels for oil and natural gas production. Since the permeability represents the mobility of the fluid in the uniform pore medium and under a certain pressure difference, for fractured compact sandstone reservoirs, the mobility of oil and natural gas in the fractures cannot be expressed by the permeability of the uniform pore medium.
At present, for carbonate fracture-cave reservoirs, a pipe flow model yield index is introduced to measure the flowability of oil and natural gas in carbonate fractures and erosion cavities. Considering that only fractures exist in the fractured tight sandstone reservoir, the scheme for measuring the flowability of oil and natural gas through the pipe flow model production index is not suitable for the fractured tight sandstone reservoir.
In conclusion, how to accurately measure the flowability of the fractured compact sandstone reservoir is a problem which needs to be solved urgently at present.
Disclosure of Invention
The invention provides a method, a device and a storage medium for calculating a fracture laminar flow index, which are used for accurately measuring the flowability of a fractured compact sandstone reservoir.
In a first aspect, the present invention provides a method of calculating a fracture laminar flow index, the method comprising:
acquiring a borehole wall conductivity image of a target well;
performing electrical imaging image segmentation processing on the well wall conductivity image based on a button electrode conductivity curve to obtain a well wall target sub-image of a target well, wherein the well wall target sub-image comprises a crack target;
acquiring the geometric parameters of the crack target according to the well wall target sub-image;
and acquiring a fracture laminar flow index of the target well corresponding to the well wall conductivity image according to the geometric parameters of the fracture target and the number of pixels of the well wall conductivity image, wherein the fracture laminar flow index is used for expressing the flowability of the fluid in a fractured reservoir.
Further, the borehole wall conductivity image is obtained by performing point-by-point calibration on the data of the shallow lateral resistivity.
Further, the acquiring the geometric parameters of the fracture target according to the borehole wall target sub-image includes:
acquiring geometric parameters of each target contained in the well wall target subimage by adopting a target shape parameter algorithm based on the edge point set;
determining a crack target contained in the well wall target sub-image according to the geometric parameters of each target and preset conditions;
and acquiring the number of pixel points of the crack target.
Further, the obtaining of the fracture laminar flow index of the target well corresponding to the borehole wall conductivity image according to the geometric parameters of the fracture target and the number of the pixel points of the borehole wall conductivity image includes:
according to the number of pixel points of the crack target in the image frame and the number of pixel points of the image frame of the borehole wall conductivity image, utilizing a formula
Acquiring a fracture laminar flow index of the target well corresponding to the well wall conductivity image, wherein C isFZDenotes the fracture laminar index, said AFiNumber of pixel points representing ith said fracture target, said FzAnd the number of the image frame pixel points of the borehole wall conductivity image is represented, and the numerator in the formula sums the squares of the pixel points of all crack targets in the borehole wall conductivity image.
Further, the geometric parameters include one or more of the following parameters:
aspect ratio, viewing angle, flatness, number of single target pixel points.
Further, after acquiring the fracture laminar flow index of the target well corresponding to the borehole wall conductivity image according to the geometric parameters of the fracture target and the number of the pixel points of the borehole wall conductivity image, the method further includes:
acquiring the average value and the root-mean-square difference of the fracture laminar flow indexes corresponding to different well sections of the target well according to the fracture laminar flow indexes;
and establishing a reservoir grading standard according to the average value and the root-mean-square difference of the laminar flow indexes of the fractures corresponding to the target wells in different well sections, wherein the reservoir grading standard is used for evaluating a new well.
Further, the establishing of the reservoir grade division standard according to the average value and the root-mean-square difference of the laminar flow indexes of the fractures corresponding to the multiple target wells in different well sections comprises the following steps:
and establishing the reservoir grade division standard by adopting a cross plot method according to the average value and the root-mean-square difference of the laminar flow indexes of the fractures corresponding to the target wells in different well sections.
In a second aspect, the present invention provides an apparatus for calculating a fracture laminar flow index, the apparatus comprising:
the first acquisition module is used for acquiring a borehole wall conductivity image of a target well;
the segmentation module is used for carrying out electrical imaging image segmentation processing on the well wall conductivity image on the basis of a button electrode conductivity curve to obtain a well wall target sub-image of a target well, wherein the well wall target sub-image comprises a crack target;
the second acquisition module is used for acquiring the geometric parameters of the crack target according to the well wall target sub-image;
and the calculation module is used for acquiring a fracture laminar flow index of the target well corresponding to the well wall conductivity image according to the geometric parameters of the fracture target and the area of the well wall conductivity image, wherein the fracture laminar flow index is used for representing the flowability of the fluid in a fractured reservoir.
In a third aspect, the present invention further provides an apparatus for calculating a fracture laminar flow index, the apparatus comprising: a memory and a processor;
the memory stores program instructions;
the processor executes the program instructions to perform the method of the first aspect.
In a fourth aspect, the present invention also provides a storage medium comprising a program;
the program is for performing the method of the first aspect when executed by a processor.
The invention provides a method, a device and a storage medium for calculating a fracture laminar flow index, wherein a well wall conductivity image of a target well is obtained, the well wall conductivity image is segmented, a well wall target sub-image of the target well is obtained, the well wall target sub-image comprises a fracture target, further, a geometric parameter of the fracture target is obtained according to the well wall target sub-image, then, the fracture laminar flow index of the well wall conductivity image corresponding to the target well is obtained according to the geometric parameter of the fracture target and the area of the well wall conductivity image, and the fracture laminar flow index is used for expressing the flowability of fluid in a fractured reservoir. The method comprises the steps of obtaining a borehole wall conductivity image of a target layer by adopting an electrical imaging logging technology, obtaining a fracture laminar flow index of a corresponding well section, and measuring the flowability of a fluid in fractured compact sandstone by using the fracture laminar flow index.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings needed to be used in the description of the embodiments or the prior art will be briefly introduced below, and it is obvious that the drawings in the following description are some embodiments of the present invention, and for those skilled in the art, other drawings can be obtained according to these drawings without creative efforts.
Figure 1 is a schematic representation of fluid flow in a fractured tight sandstone reservoir;
FIG. 2 is a schematic flow chart of a first embodiment of a method for calculating a fracture laminar flow index according to the present invention;
FIG. 3 is a graph of the relationship between the average of the fracture laminar flow indexes of different well sections of a plurality of target wells and the corresponding gas production rate index;
FIG. 4 is a schematic diagram of a borehole wall conductivity image of a target borehole in a preset borehole section and a corresponding borehole wall target subimage;
FIG. 5 is a schematic flow chart of a second embodiment of the method for calculating a fracture laminar flow index according to the present invention;
FIG. 6 is a first schematic diagram of the length, width and angle of view of the targets in the borehole wall target sub-image;
FIG. 7 is a second schematic diagram of the length, width and angle of view of the targets in the borehole wall target sub-image;
FIG. 8 is a schematic illustration of a constant laminar flow of a fluid between infinitely extending, finite length plates;
FIG. 9 is a schematic flow chart of a third embodiment of the method for calculating a fracture laminar flow index according to the present invention;
FIG. 10 is an exemplary cross-sectional view provided by the present invention;
FIG. 11 is a schematic diagram of the electrical imaging logging data, fracture laminar flow index and reservoir classification results of the KESX-Y well 6745 and 6800 m well section;
FIG. 12 is a schematic diagram of the results of electrical imaging logging data, fracture laminar flow index and reservoir grade division of a DB1XX well 5922-5949-meter well section;
FIG. 13 is a schematic structural diagram of a first embodiment of an apparatus for calculating a fracture laminar flow index according to the present invention;
FIG. 14 is a schematic structural diagram of a second embodiment of the apparatus for calculating a fracture laminar flow index according to the present invention;
fig. 15 is a schematic structural diagram of a third apparatus for calculating a fracture laminar flow index according to the present invention.
Detailed Description
In order to make the objects, technical solutions and advantages of the embodiments of the present invention clearer, 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 some, but not all, embodiments of the present invention. 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.
Figure 1 is a schematic representation of fluid flow in a fractured tight sandstone reservoir. As shown in fig. 1, the pore space in fractured tight sandstone reservoirs is mainly divided into two types, rock matrix pores and fractures. The rock matrix porosity and the flowability of the fractured compact sandstone reservoir are both low, the flow of the fluid in the rock matrix with low flowability is Darcy flow, and the flow path is short and mainly flows into the fractures. The oil, gas, etc. stored in the rock matrix first flow into the fractures, as shown in fig. 1, the oil, gas, etc. flow into the fractures in the direction indicated by the arrows and then flow through the fractures into the wellbore, so the fractures are the main production channels for oil, gas, etc. in the fractured tight sandstone reservoir.
The fracture laminar flow index is used for measuring the flowability of fluid in fractured reservoirs, and is particularly used for measuring the flowability of fluid in fractured tight sandstone reservoirs. The higher the flowability of the fluid in the fractured tight sandstone reservoir, the higher the energy production of the fractured tight sandstone reservoir. Conversely, the lower the fluid mobility in the fractured tight sandstone reservoir, the lower the energy production of the fractured tight sandstone reservoir. Therefore, the flowability of fluids in fractured tight sandstone reservoirs is of great importance in exploration and development.
Meanwhile, because the method for calculating the flowability in the prior art cannot be applied to the fractured compact sandstone reservoir, based on the technical problems, the invention provides the method for calculating the fracture laminar flow index, so that the flowability of the fluid in the fractured compact sandstone reservoir is accurately measured, and data support is provided for exploration and development.
Fig. 2 is a schematic flow chart of a first embodiment of the method for calculating a fracture laminar flow index provided by the present invention. As shown in fig. 2, the method of the present embodiment includes:
s201, acquiring a borehole wall conductivity image of the target well.
The electric imaging well logging technology is a well logging method for measuring the conductivity image of the stratum near the well wall. Because the conductivities of different geologies are different, a borehole wall conductivity image capable of reflecting geological conditions such as cracks, bedding and the like in a stratum near a borehole wall can be obtained through an electrical imaging logging technology. The electrical imaging logging technology may be Formation Micro-resistivity scanning imaging (FMI) logging technology, enhanced Micro-resistivity scanning imaging (XRMI) logging technology, and the like.
For example, in a fractured tight sandstone formation, under water-based mud conditions, a high conductivity mud invades an open fracture, so that the conductivity at the effective fracture is significantly different from that of the background rock matrix, and the effective fracture target and the rock matrix appear to be characterized differently in the borehole wall conductivity image. In addition, the characteristics of the effective fracture target and the micro-bedding target in the reservoir and the background noise target in the borehole wall conductivity image are different. Therefore, the geology of the fractured compact sandstone reservoir can be accurately measured by the electric imaging logging technology.
In this embodiment, a borehole wall conductivity image of the target borehole may be obtained by the electrical imaging logging instrument. The borehole wall conductivity image of the target borehole may be a borehole wall conductivity image of the whole borehole section of the target borehole, may also be a borehole wall conductivity image of the target borehole in a preset borehole section, or may also be a borehole wall conductivity image of the target borehole in a preset depth, which is not limited in the embodiments of the present invention.
S202, performing electric imaging image segmentation processing on the borehole wall conductivity image based on the button electrode conductivity curve to obtain a borehole wall target sub-image of the target well.
And the sub-image of the well wall target comprises a crack target.
In this embodiment, an example of obtaining a borehole wall conductivity image of a target borehole at a preset depth is described.
In order to identify an effective crack target from the borehole wall conductivity image, the obtained borehole wall conductivity image of the target borehole is subjected to electrical imaging image segmentation processing based on the button electrode conductivity curve in the step to obtain a plurality of borehole wall target sub-images. And the well wall target sub-image comprises a fracture target. The effective crack target can be accurately segmented from the well wall conductivity image by adopting the electrical imaging image segmentation processing based on the button electrode conductivity curve.
As is often the case, the borehole wall conductivity image typically includes one or more of a fracture target, an in-reservoir micro-bedding target, and a background noise target. Therefore, it can be understood that the borehole wall target sub-image may also include an in-reservoir micro-texture target and/or a background noise target. Of course, the borehole wall target sub-image may not include a fracture target, but only include an in-reservoir micro-texture target and/or a background noise target. The borehole wall target sub-image may also contain only rock matrix.
It should be noted that the well wall conductivity image is segmented to obtain non-overlapping portions of the plurality of well wall target sub-images, so that it is ensured that the crack targets identified from the well wall target sub-images are not repeatedly calculated, and the accuracy of the crack laminar flow index obtained according to the well wall conductivity image is high.
And S203, acquiring the geometric parameters of the crack target according to the sub-image of the well wall target.
Because the borehole wall target sub-image obtained in step S202 contains the fracture target, the geometric parameters of the fracture target contained in the borehole wall target sub-image can be obtained according to the borehole wall target sub-image.
Specifically, a plurality of borehole wall target sub-images are obtained through segmentation processing according to the borehole wall conductivity image with the preset depth, and geometric parameters of all crack targets contained in the electric imaging image of the target well with the preset depth are obtained.
And S204, acquiring a fracture laminar flow index of the well wall conductivity image corresponding to the target well according to the geometric parameters of the fracture target and the number of pixel points of the well wall conductivity image.
Wherein the fracture laminar flow index is used to represent the mobility of fluids in a fractured reservoir. Specifically, according to the geometric parameters of all crack targets contained in the borehole wall conductivity image of the target borehole at the preset depth and the number of pixel points of the borehole wall conductivity image, calculation is performed through a preset algorithm, and therefore the crack laminar flow index of the borehole wall conductivity image corresponding to the target borehole is obtained.
In the embodiment, a borehole wall target sub-image of the target well is obtained by obtaining a borehole wall conductivity image of the target well and performing electrical imaging image segmentation processing on the borehole wall conductivity image based on a button electrode conductivity curve, wherein the borehole wall target sub-image comprises a fracture target, further, a geometric parameter of the fracture target is obtained according to the borehole wall target sub-image, and then, a fracture laminar flow index of the borehole wall conductivity image corresponding to the target well is obtained according to the geometric parameter of the fracture target and the number of pixels of the borehole wall conductivity image, wherein the fracture laminar flow index is used for indicating the flowability of a fluid in a fractured reservoir. In the embodiment, an electrical imaging logging technology is adopted to obtain a borehole wall conductivity image of a target well, a corresponding fracture laminar flow index is further obtained according to the borehole wall conductivity image with high accuracy, and the flowability of the fluid in the fractured compact sandstone reservoir is accurately represented through the fracture laminar flow index.
The method in the embodiment is applied to a plurality of target wells of fractured compact sandstone reservoirs in big north-depths of grazing area exemplarily, and the application effect is remarkable.
Specifically, FMI electrical imaging logging information of 21 target wells in the northeast and the Kyork region and XRMI electrical imaging logging information of 3 target wells are processed by an imaging image segmentation method based on an electrical conductivity curve of an electrical imaging button electrode, wherein the electrical imaging logging information comprises a well wall electrical conductivity image, and further parameters such as the crack surface porosity and the crack laminar flow index of the target wells are extracted. According to the obtained data, 1 port of oil test is removed, and the conclusion is that the target well of the water layer, 1 port of the target well with poor electric imaging logging data quality and 4 ports of the target well with large influence on well wall conductivity image segmentation caused by micro-bedding in the reservoir are removed. That is, after 6 target wells with abnormal data are removed, 18 target wells with normal data are obtained.
The fracture laminar flow indexes of 18 normal target wells and the corresponding meter gas production indexes are subjected to statistical analysis, and the obtained statistical analysis results are shown in fig. 3. the abscissa in fig. 3 is the average value of the fracture laminar flow indexes of the well sections, and the ordinate is the meter gas production index of the well sections, "●" represents the data of the target wells in the deep region, "△" represents the data of the target wells in the northern region.
According to the relationship between the average value of the fracture laminar flow indexes of different well sections of the multiple target wells and the corresponding meter gas production index shown in fig. 3, the average value of the fracture laminar flow indexes of different well sections is linearly related to the meter gas production index shown in fig. 3, and it can be known that in a fractured compact sandstone reservoir, the larger the fracture laminar flow index obtained according to a well wall conductivity image is, the higher the flowability of fluid in the reservoir is, and the higher the reservoir yield is, and conversely, the smaller the fracture laminar flow index obtained according to the well wall conductivity image is, the lower the flowability of fluid in the reservoir is, and the lower the reservoir yield is.
Based on the embodiment shown in fig. 2, the borehole wall conductivity image may be a borehole wall conductivity image that is point-by-point scaled using data of shallow lateral resistivity. At this time, S202, the borehole wall conductivity image is subjected to the electrical imaging image segmentation processing based on the button electrode conductivity curve to obtain a borehole wall target sub-image of the target borehole, which may specifically be: and performing electric imaging image segmentation processing based on a button motor conductivity curve on the well wall conductivity image subjected to point-by-point scaling by adopting the shallow lateral resistivity data to obtain a well wall target sub-image of the target well.
The well wall conductivity image is obtained by adopting data of shallow lateral resistivity to scale point by point, so that the accuracy of the well wall conductivity image is higher, and the accuracy of the crack laminar flow index calculated according to the well wall conductivity image is higher.
Illustratively, FIG. 4 shows a borehole wall conductivity image of the target well at a predetermined interval and corresponding borehole wall target sub-images. The borehole wall conductivity image in fig. 4 is a borehole wall conductivity image obtained by performing point-by-point calibration on shallow lateral resistivity data. In the figure, (a) a borehole wall conductivity image after point-by-point calibration is carried out by adopting data of shallow lateral resistivity, and (b) the image is a borehole wall target sub-image.
Fig. 5 is a schematic flow chart of a second method for calculating a fracture laminar flow index according to an embodiment of the present invention. As shown in fig. 5, based on the process shown in fig. 2, S203, acquiring geometric parameters of the fracture target according to the sub-image of the borehole wall target, may include the following steps:
s501, acquiring geometric parameters of each target contained in the borehole wall target sub-image by adopting a target shape parameter algorithm based on the edge point set.
Specifically, edge pixel points of each target in the borehole wall conductivity image are picked up and recorded through a target shape parameter algorithm based on an edge point set, and various geometric parameters of the target are calculated according to the edge pixel points of the target. The targets here include fracture targets, in-reservoir micro-bedding targets and background noise targets. It should be noted that the borehole wall target sub-image may also contain only rock matrix. Specifically, an edge point set of the crack target is picked from the segmented well wall target sub-images, the edge point set of the crack target is further encoded to obtain a direction chain code of the edge point set of the crack target, and then the geometric parameters of the crack target are calculated according to the direction chain code of the edge point set of the crack target.
Optionally, the geometric parameters may include one or more of the following parameters: aspect ratio, viewing angle, flatness, number of single target pixel points, etc. Wherein, the aspect ratio is the ratio of the length to the width of the target.
Illustratively, the length, width and angle of view of the targets in the borehole wall target sub-images may be as shown in fig. 6 and 7.
S502, determining the crack targets contained in the well wall target sub-images according to the geometric parameters of each target and preset conditions.
Since the sub-image of the well wall target may contain other targets besides the fracture target, the fracture target needs to be accurately identified from all the targets. According to a possible implementation mode, preset conditions met by the crack targets can be preset according to historical experience or experimental data, and the crack targets can be accurately identified from all targets contained in the well wall targets according to the geometric parameters and the preset conditions of each target. Illustratively, the preset condition may specifically be: the roundness is more than 20, the length-width ratio is more than 4.5, the absolute value of the viewing angle is more than 30 degrees, and the target meeting the preset condition is determined as a crack target.
S503, acquiring the number of pixel points of the crack target.
If the geometric parameters obtained in S501 include the number of single-target pixel points, the step may be understood as directly reading the number of pixel points corresponding to the crack target. If the geometric parameters acquired in S501 do not include the number of single-target pixels, the number of single-target pixels may be calculated according to the acquired geometric parameters, such as the length and the width of the fracture target, to acquire the number of single-target pixels. The present invention does not limit the manner of obtaining the number of pixel points of the crack target.
In some embodiments, the step S204 of obtaining the fracture laminar flow index of the borehole wall conductivity image corresponding to the target well according to the geometric parameters of the fracture target and the number of pixels of the borehole wall conductivity image may include:
according to the number of pixel points of the crack target in the image frame and the number of pixel points of the image frame of the borehole wall conductivity image, a formula is utilized
Acquiring a fracture laminar flow index of the target well corresponding to the well wall conductivity image, wherein C isFZDenotes the fracture laminar index, said AFiNumber of pixel points representing ith said fracture target, said FzAnd the number of the image frame pixel points of the borehole wall conductivity image is represented, and the numerator in the formula sums the squares of the pixel points of all crack targets in the borehole wall conductivity image.
Specifically, the pixel points A of all crack targets corresponding to the well wall are countedFiAnd the number of image frame pixel points F of the borehole wall conductivity imagezSubstituting the obtained value into the formula to obtain the fracture laminar flow index corresponding to the borehole wall conductivity image. Wherein, the numerator in the formula is represented by summing the squares of the pixel points of all fracture targets in the borehole wall conductivity image.
The following describes the derivation of the fracture laminar flow index according to the present invention.
For fractured compact sandstone reservoirs, fractures are the main channels for oil and natural gas production. In the invention, the pressure system of the fractured compact sandstone reservoir is assumed to be stable, the flow of the oil and the natural gas is stable and constant in the production process, and the volume compressibility of the oil and the natural gas can not be considered. Therefore, the flow of oil and gas in the fracture is regarded as the flow of viscous incompressible fluid in the fracture. Near the wellbore, the flow of oil and gas in the fracture can be approximately equivalent to a constant laminar flow problem between infinitely extending, finite length plates through the wellbore.
Fig. 8 is a schematic view of a constant laminar flow of a fluid between wirelessly extending, finite length plates, as shown in fig. 8, where H represents the distance from the centerline position of the infinitely extending, finite length plate to the upper plate, the x-axis represents the direction of fluid flow, and the y-axis represents the distance from the ordinate to the centerline position between the plates.
The solution of the laminar flow problem of the Navier-Stokes equation of the incompressible viscous fluid between infinitely extended and finite plates is as follows:
in the formula (1), u is the flow rate of the fluid, η is the viscosity of the fluid,
h represents the distance from the midline position of the infinitely extended, finite length plate to the upper plate, which is the pressure gradient in the direction of fluid flow. From equation (1), the fluid flow velocity distribution between infinitely extended, finite plates is parabolic, similar to the flow velocity distribution of the fluid flow of an incompressible fluid in a circular pipe. Thus, the problem of constant laminar flow between infinitely extended, finite length plates is equivalent to an irregularly shaped circular tube flow. The flow expression of the Hagen-Poiseuille law describing the flow of incompressible fluids in a single circular tube is:
in the formula (2), Q is the flow rate flowing through the thin tube,
the pressure gradient in the flow direction of the tubule is shown, and A is the cross-sectional area of the tubule.
For the flow of fluid in a limited long fracture in a fractured compact sandstone reservoir to a shaft, the fractures are unified and equivalent to the flow of fluid in thin pipes with different cross-sectional areas to the shaft. The flow rate of the fluid flowing to the wellbore is calculated by the formula:
in the formula (3), AFiThe cross-sectional area of the ith crack equivalent to a thin tube at the well wall,
is the pressure gradient of the ith equivalent to the fracture of the tubule.
Assuming that the flow of fluid from deep radial depths to the wellbore in a reservoir in a real well is a planar radial flow, the pressure differential exists only radially from the wellbore, with no cross-flow between different depths. Let reSupply radius, r, to the formationwIs the borehole radius, peSupply edge pressure, p, to the formationwFor wellbore pressure, the pressure gradient of each tubule is the same, and the reservoir thickness is h. The planar radial flow in the borehole is symmetric about the borehole center, and in the cylindrical coordinate system, the flow rate of the fluid in the borehole can be expressed as:
integrating the supply radius to obtain a flow formula of laminar model fluid with different cross-sectional areas flowing to a shaft of the fractured compact sandstone stratum:
multiplying both sides of the formula (5) by the drainage area A of the shafth＝2πrwSquare of h is
Defining fracture laminar flow index
Laminar flow index of crack CFhIs a parameter that indicates the flowability of a fluid in a fractured tight sandstone reservoir.
As can be seen from the formula (6), the fractured compact sandstoneEnergy production and pressure gradient within supply radius of reservoir
Is proportional to the magnitude of the formation fluid, is inversely proportional to the viscosity η of the formation fluid, and is proportional to the drainage area a of the wellborehIs proportional to the square of; laminar flow index to fracture CFhIs in direct proportion. Pressure gradient in reservoir supply radius, formation fluid properties and drainage area A of well borehAt a certain time, the laminar flow index of the crack CFhThe larger the flow rate of the fluid in the fractured compact sandstone reservoir is, the better the yield of the fractured compact sandstone reservoir is; conversely, fracture laminar flow index CFhThe smaller the mobility of the fluid in the fractured tight sandstone reservoir and the lower the production of the fractured tight sandstone reservoir.
The longitudinal length of the image frame is the sampling interval of calculating the crack laminar flow index point by point, because the polar plate of the electric imaging logging can not completely cover the whole well wall and the pixel point in the single image frame can only cover the well wall when the electric imaging logging technology is used for logging, therefore, the well-wall coverage rate of the well-wall conductivity image is β, and the area of the image frame of the well-wall conductivity image is FzWherein, the area of the image frame can be represented by the number of pixel points of the image frame, and the actual borehole wall area corresponding to the area of the image frame of the borehole wall conductivity image is
In this case, the formula (6) becomes
The crack laminar flow index corresponding to the borehole wall conductivity image becomes
Formula (7) is changed into
Wherein Q iszIs the flow within one image frame depth interval. For a given image frame area, the pressure gradient within the fluid supply radius is constant, k being a constant. Calculating the image frame of each borehole wall conductivity image to obtain a point-by-point fracture laminar flow index CFZLaminar flow index through crack CFZAccurately representing the amount of formation fluid mobility.
In the embodiment, a borehole wall target sub-image of a target well is obtained by obtaining a borehole wall conductivity image of the target well, performing electrical imaging image segmentation processing on the borehole wall conductivity image based on a button electrode conductivity curve, wherein the borehole wall conductivity image is the borehole wall conductivity image calibrated by using data of shallow lateral resistivity, further, geometric parameters of each target contained in the borehole wall target sub-image are obtained by using a target shape parameter algorithm based on an edge point set, crack targets contained in the borehole wall target sub-image are determined according to the geometric parameters and preset conditions of each target, pixel points of the crack targets are obtained, and a crack laminar flow index of the borehole wall conductivity image corresponding to the target well is obtained according to a calculation formula of the crack laminar flow index. The method in the embodiment performs point-by-point scale processing by adopting the data of the shallow lateral resistivity, so that the obtained formation resistivity data is more accurate, and further, the geometric parameters of the target are obtained by adopting a target shape parameter algorithm based on the edge point set, so that the crack target can be accurately identified, and the accuracy of the laminar flow index of the crack is improved.
By adopting the steps of the embodiment, the fracture laminar flow indexes of the target well at a plurality of sampling points can be obtained, and the flowability of the fluid at different sampling points in the fractured reservoir can be accurately represented.
Fig. 9 is a schematic flow chart of a third embodiment of the fracture laminar flow index calculation method provided by the present invention. Referring to fig. 9, on the basis of the embodiment shown in fig. 2, after obtaining the fracture laminar flow index of the borehole wall conductivity image corresponding to the target well according to the geometric parameters of the fracture target and the number of pixels of the borehole wall conductivity image, S204 may further include:
s901, obtaining the average value and the root-mean-square difference of the fracture laminar flow indexes corresponding to different well sections of the target well according to the fracture laminar flow indexes.
Specifically, after fracture laminar flow indexes of a plurality of sampling points of a preset well section of the target well are obtained, an average value of the fracture laminar flow indexes of the target well at the preset well section can be obtained according to a formula (9):
wherein the content of the first and second substances,
representing the average value of the laminar flow indexes of the fractures of the preset well section, N is the number of sampling points in the preset well section, t represents the t-th sampling point in the preset well section, CFZtThe fracture laminar flow index of the tth sampling point is shown.
Further, the root-mean-square difference of the fracture laminar flow index of the target well in the preset well section is obtained by adopting a formula (10):
wherein σCFZAnd the root mean square difference of the laminar flow indexes of the fractures of the preset well section is shown.
S902, establishing a reservoir grade division standard according to the average value and the root mean square difference of the laminar flow indexes of the fractures corresponding to the target wells in different well sections.
Wherein the reservoir rating criteria are used to evaluate new wells. The new well may be the target well described above.
Because the linear correlation exists between the fracture laminar flow index and the reservoir meter-out gas production index, the reservoir grade division standard can be established according to the mean value of the fracture laminar flow indexes of different well sections of the multiple wells and the root-mean-square difference of the fracture laminar flow indexes. In practical applications, the new well has similar geological conditions to those of the well used to establish the reservoir ranking criteria. Therefore, by adopting the reservoir grade division standard, the reservoir yield of the new well can be estimated according to the logging data of the new well.
It should be noted that, in the method for calculating a fracture layer flow index provided in this embodiment, a reservoir classification standard may also be established according to other parameter information of the target well, for example, variances of fracture layer flow indexes corresponding to different well sections of the target well. The process of establishing the reservoir ranking standard is similar to the step of establishing the reservoir ranking standard according to the average value of the fracture laminar flow index and the root-mean-square difference of the fracture laminar flow index in this embodiment, and details are not repeated here.
One possible implementation manner may specifically be: and establishing a reservoir grade division standard by adopting an intersection graph method according to the average value and the root-mean-square difference of the laminar flow indexes of the fractures corresponding to the target wells in different well sections.
The cross-plot method refers to a plotting and interpretation technique for well logging data. According to the method, an intersection graph is drawn by using the average value and the root-mean-square difference of the fracture laminar flow indexes of a plurality of target wells corresponding to different well sections, the reservoir level is determined according to the intersection graph, and a reservoir level division standard is established. The reservoir grade division standard established by the method in the embodiment can be used for evaluating the reservoir energy storage condition of a new well, so that data support is provided for energy development.
Exemplary, the present invention will be described in detail with respect to the establishment of reservoir stratifying criteria using a cross-plot approach and the use of the established reservoir stratifying criteria for the evaluation of new wells.
Fig. 10 is an exemplary cross-sectional view provided by the present invention. Specifically, fig. 10 is a cross-plot that is drawn according to the average value of the fracture laminar flow indexes corresponding to different well sections of a plurality of target wells in the north-south kern region and the root-mean-square difference of the fracture laminar flow indexes, and a reservoir classification standard is established according to the cross-plot. Wherein, the abscissa is the average value of the laminar flow indexes of the cracks, and the ordinate is the root-mean-square deviation of the laminar flow indexes of the cracks.
The reservoir grades are divided into the following three categories:
the average value of the fracture laminar flow index of the I type reservoir is more than 0.0076%, the root mean square difference of the fracture laminar flow index is more than 0.0106%, and the gas production rate of the I type reservoir is more than 1000m 3/d/m/Mpa.
The average value of the fracture laminar flow indexes of the II-type reservoirs is more than 0.0040 percent and less than 0.0076 percent, the root mean square difference of the fracture laminar flow indexes is more than 0.0057 percent and less than 0.0106 percent, and the gas production rate of the II-type reservoirs is more than 100m3/d/m/Mpa and less than 1000m 3/d/m/Mpa.
The average value of the fracture laminar flow indexes of the III type reservoirs is less than 0.0040 percent, the root mean square difference of the fracture laminar flow indexes is less than 0.0057 percent, and the gas production rate of the III type reservoirs is less than 100m 3/d/m/Mpa.
As shown in fig. 10, "◆" represents a class i reservoir, "■" represents a class ii reservoir, and "●" represents a class iii reservoir.
The method in the embodiment is applied to 2 new wells in the northern-King depth region, wherein the obtained electrical imaging logging data, fracture laminar flow index and reservoir classification results of the 2 new wells are shown in fig. 11 and 12.
In addition, FIG. 11 is a schematic diagram of the electrical imaging logging data, fracture laminar flow index and reservoir classification results of the KESX-Y well 6745-6800-meter well section. Referring to fig. 11, the 1 st track is a lithology curve track, the 2 nd track indicates well depth, the 3 rd track is an array induction resistivity curve track, the 4 th track is a three-porosity curve track, the 6 th track is a borehole wall conductivity image which is subjected to point-by-point scaling by using data of shallow lateral resistivity, the 7 th track is a segmented borehole wall target sub-image, the 8 th track is a fracture target edge image, the 9 th track is calculated fracture surface porosity (FFPHIT) and fracture laminar flow index (XFPHIT), and the 10 th track is a divided reservoir level. Note that, the 5 th trace is the fracture porosity calculated from the induction log data.
The well tests 6745-6900-meter well sections in 3, 5 to 3, 21 in 2014 in a well completion acidification mode, a 10mm oil nozzle is used for blowout prevention to solve production, the oil pressure is 95.888MPa, the daily gas production is 1199580 square, the test conclusion is that a gas reservoir is obtained, and the calculated gas production index per meter is 1799.56m3/d/m/MPa and is a type I reservoir. And dividing reservoir sections and reservoir levels according to conventional logging information, imaging logging information and the fracture laminar flow index calculated point by point, wherein 6 reservoir sections are arranged in the well testing section, and the rest 5 reservoir sections are I reservoir layers except the reservoir section at the bottom of the well which is the II reservoir layer. And the classification result of the reservoir stratum with the fracture laminar flow index is consistent with the oil testing result.
FIG. 12 is a diagram illustrating the results of electrical imaging logging data, fracture laminar flow index and reservoir grade division of a DB1XX well 5922-5949-meter well section. The acid fracturing test is carried out on the 5922-sand 5949-meter well section of the well, the oil nozzle is 8mm, the oil pressure is 0MPa, the water yield in the year of breaking down is 4.4 cubic meters, and the reservoir is a III-class reservoir. And dividing reservoir sections and reservoir levels according to conventional logging information, electrical imaging logging information and the fracture laminar flow index calculated point by point, wherein 3 reservoir sections are arranged in the well testing section, and the 3 reservoir sections are all III-type reservoirs.
And the reservoir grade division result of the reservoir grade division standard established according to the fracture laminar flow index is consistent with the oil testing result.
The method provided by the embodiment can accurately evaluate the reservoir energy storage condition of the new well and provide data support for exploration and development of the new well.
According to the new well reservoir classification results shown in fig. 11 and 12, it can be known that the larger the mean value and the root mean square difference of the fracture laminar flow index are, the higher the mobility of reservoir fluid is, the higher the reservoir classification is, and the higher the production is; the smaller the mean and root mean square deviation of the fracture laminar flow index, the lower the mobility of the reservoir fluid, the lower the reservoir grade, and the lower the production.
Fig. 13 is a schematic structural diagram of a first embodiment of a fracture laminar flow index calculation apparatus provided in the present invention. As shown in fig. 13, the apparatus 10 of the present embodiment may include: the device comprises a first acquisition module 11, a segmentation module 12, a second acquisition module 13 and a calculation module 14.
The first acquisition module 11 is used for acquiring a borehole wall conductivity image of the target well.
And the segmentation module 12 is configured to perform electrical imaging image segmentation processing on the borehole wall conductivity image based on the button electrode conductivity curve to obtain a borehole wall target sub-image of the target well, where the borehole wall target sub-image includes a fracture target.
And the second acquisition module 13 is used for acquiring the geometric parameters of the crack target according to the sub-image of the borehole wall target.
And the calculation module 14 is configured to obtain a fracture laminar flow index of the borehole wall conductivity image corresponding to the target well according to the geometric parameters of the fracture target and the number of pixels of the borehole wall conductivity image, where the fracture laminar flow index is used to indicate flowability of the fluid in the fractured reservoir.
The apparatus of this embodiment may be used to implement the technical solutions of the method embodiments shown in fig. 2 and fig. 5, and the implementation principles and technical effects are similar, which are not described herein again.
Fig. 14 is a schematic structural diagram of a second embodiment of the fracture laminar flow index calculation apparatus provided in the present invention. As shown in fig. 12, the apparatus 20 of the present embodiment further includes, on the basis of the embodiment shown in fig. 13: a third obtaining module 15 and a building module 16.
The third obtaining module 15 is configured to obtain an average value and a root-mean-square difference of the fracture laminar flow indexes corresponding to the target well in different well sections according to the fracture laminar flow indexes.
The establishing module 16 is configured to, after acquiring the fracture laminar flow indexes of the well wall conductivity images corresponding to the target wells according to the geometric parameters of the fracture target and the areas of the well wall conductivity images, establish a reservoir classification standard according to an average value and a root mean square difference of the fracture laminar flow indexes corresponding to the target wells in different well sections, where the reservoir classification standard is used for evaluating a new well.
Specifically, the establishing module 16 establishes a reservoir classification standard according to the average value and the root-mean-square difference of the laminar flow indexes of the fractures corresponding to the target wells in different well sections by using an intersection graph method.
In addition, in this embodiment, the segmentation module 12 is specifically configured to perform electrical imaging image segmentation processing on the borehole wall conductivity image based on the button electrode conductivity curve to obtain a borehole wall target sub-image of the target borehole, where the borehole wall conductivity image is a borehole wall conductivity image that is scaled point by using shallow lateral resistivity data.
The second obtaining module 13 is specifically configured to obtain a geometric parameter of each target included in the borehole wall target sub-image by using a target shape parameter algorithm based on the edge point set, determine a fracture target included in the borehole wall target sub-image according to the geometric parameter of each target and a preset condition, and obtain a number of pixel points of the fracture target.
A calculating module 14, specifically configured to utilize a formula according to the number of pixel points of the crack target in the image frame and the number of pixel points of the image frame of the borehole wall conductivity image
Acquiring a fracture laminar flow index of the target well corresponding to the well wall conductivity image, wherein C isFZDenotes the fracture laminar index, said AFiNumber of pixel points representing ith said fracture target, said FzAnd the number of the image frame pixel points of the borehole wall conductivity image is represented, and the numerator in the formula sums the squares of the pixel points of all crack targets in the borehole wall conductivity image.
Optionally, the geometric parameters include one or more of the following parameters: aspect ratio, viewing angle, flatness, number of single target pixel points, etc.
The apparatus of this embodiment may be used to implement the technical solution of the method embodiment shown in fig. 9, and the implementation principle and the technical effect are similar, which are not described herein again.
Fig. 15 is a schematic structural diagram of a third embodiment of the fracture laminar flow index calculation apparatus provided in the present invention. As shown in fig. 15, the apparatus 150 of the present embodiment includes: memory 151, processor 152.
The memory 151 may be a separate physical unit, and may be connected to the processor 152 via the bus 153. The memory 151 and the processor 152 may also be integrated together, implemented by hardware, and the like.
The memory 151 is used to store a program implementing the above method embodiments, which is called by the processor 152 to perform the operations of the above method embodiments.
Alternatively, when part or all of the method of the above embodiment is implemented by software, the electronic device 150 may only include a processor. The memory for storing the program is located outside the crack laminar flow index calculation device 150, and the processor is connected with the memory through a circuit/wire and is used for reading and executing the program stored in the memory.
The Processor 152 may be a Central Processing Unit (CPU), a Network Processor (NP), or a combination of a CPU and an NP.
The processor 152 may further include a hardware chip. The hardware chip may be an Application-Specific Integrated Circuit (ASIC), a Programmable Logic Device (PLD), or a combination thereof. The PLD may be a Complex Programmable Logic Device (CPLD), a Field-Programmable gate Array (FPGA), General Array Logic (GAL), or any combination thereof.
The Memory 151 may include a Volatile Memory (Volatile Memory), such as a Random-Access Memory (RAM); the Memory may also include a Non-volatile Memory (Non-volatile Memory), such as a Flash Memory (Flash Memory), a Hard Disk Drive (HDD) or a Solid-state Drive (SSD); the memory may also comprise a combination of memories of the kind described above.
Additionally, the present invention also provides a program product, e.g., a computer storage medium, comprising: program for performing the above method when executed by a processor.
Those of ordinary skill in the art will understand that: all or a portion of the steps of implementing the above-described method embodiments may be performed by hardware associated with program instructions. The program may be stored in a computer-readable storage medium. When executed, the program performs steps comprising the method embodiments described above; and the aforementioned storage medium includes: various media that can store program codes, such as ROM, RAM, magnetic or optical disks.
Finally, it should be noted that: the above embodiments are only used to illustrate the technical solution of the present invention, and not to limit the same; while the invention has been described in detail and with reference to the foregoing embodiments, it will be understood by those skilled in the art that: the technical solutions described in the foregoing embodiments may still be modified, or some or all of the technical features may be equivalently replaced; and the modifications or the substitutions do not make the essence of the corresponding technical solutions depart from the scope of the technical solutions of the embodiments of the present invention.
Claims (10)
1. A method of calculating a fracture laminar flow index, comprising:
acquiring a borehole wall conductivity image of a target well;
performing electrical imaging image segmentation processing on the well wall conductivity image based on a button electrode conductivity curve to obtain a well wall target sub-image of a target well, wherein the well wall target sub-image comprises a crack target;
acquiring the geometric parameters of the crack target according to the well wall target sub-image;
and acquiring a fracture laminar flow index of the target well corresponding to the well wall conductivity image according to the geometric parameters of the fracture target and the number of pixels of the well wall conductivity image, wherein the fracture laminar flow index is used for expressing the flowability of the fluid in a fractured reservoir.
2. The method of claim 1, wherein the borehole wall conductivity image is a point-by-point scaled borehole wall conductivity image using shallow lateral resistivity data.
3. The method of claim 1, wherein the obtaining the geometric parameters of the fracture object from the borehole wall sub-object image comprises:
acquiring geometric parameters of each target contained in the well wall target subimage by adopting a target shape parameter algorithm based on the edge point set;
determining a crack target contained in the well wall target sub-image according to the geometric parameters of each target and preset conditions;
and acquiring the number of pixel points of the crack target.
4. The method of claim 1, wherein the obtaining of the fracture laminar flow index of the target well corresponding to the borehole wall conductivity image according to the geometric parameters of the fracture target and the number of pixels of the borehole wall conductivity image comprises:
according to the number of pixel points of the crack target in the image frame and the number of pixel points of the image frame of the borehole wall conductivity image, utilizing a formula
Acquiring a fracture laminar flow index of the target well corresponding to the well wall conductivity image, wherein C isFZDenotes the fracture laminar index, said AFiNumber of pixel points representing ith said fracture target, said FzAnd the number of the image frame pixel points of the borehole wall conductivity image is represented, and the numerator in the formula sums the squares of the pixel points of all crack targets in the borehole wall conductivity image.
5. The method according to any of claims 1-4, wherein the geometrical parameters comprise one or more of the following parameters:
aspect ratio, viewing angle, flatness, number of single target pixel points.
6. The method according to any one of claims 1 to 4, wherein after obtaining the fracture laminar flow index of the target well corresponding to the borehole wall conductivity image according to the geometric parameters of the fracture target and the number of pixels of the borehole wall conductivity image, the method further comprises:
acquiring the average value and the root-mean-square difference of the fracture laminar flow indexes corresponding to different well sections of the target well according to the fracture laminar flow indexes;
and establishing a reservoir grading standard according to the average value and the root-mean-square difference of the laminar flow indexes of the fractures corresponding to the target wells in different well sections, wherein the reservoir grading standard is used for evaluating a new well.
7. The method of claim 6, wherein establishing a reservoir ranking criterion based on the mean and root mean square deviation of the laminar flow indices of fractures corresponding to different well sections for a plurality of target wells comprises:
and establishing the reservoir grade division standard by adopting a cross plot method according to the average value and the root-mean-square difference of the laminar flow indexes of the fractures corresponding to the target wells in different well sections.
8. An apparatus for calculating a fracture laminar flow index, comprising:
the first acquisition module is used for acquiring a borehole wall conductivity image of a target well;
the segmentation module is used for carrying out electrical imaging image segmentation processing on the well wall conductivity image on the basis of a button electrode conductivity curve to obtain a well wall target sub-image of a target well, wherein the well wall target sub-image comprises a crack target;
the second acquisition module is used for acquiring the geometric parameters of the crack target according to the well wall target sub-image;
and the calculation module is used for acquiring a fracture laminar flow index of the target well corresponding to the well wall conductivity image according to the geometric parameters of the fracture target and the area of the well wall conductivity image, wherein the fracture laminar flow index is used for representing the flowability of the fluid in a fractured reservoir.
9. An apparatus for calculating a fracture laminar flow index, comprising: a memory and a processor;
the memory stores program instructions;
the processor executes the program instructions to perform the method of any of claims 1 to 7.
10. A storage medium, comprising: carrying out a procedure;
the program is for performing the method of any one of claims 1 to 7 when executed by a processor.
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