CN115522918A - Deep sandstone reservoir perforating well sand production pressure difference profile prediction method - Google Patents
Deep sandstone reservoir perforating well sand production pressure difference profile prediction method Download PDFInfo
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Abstract
The invention provides a method for predicting a sand production pressure difference profile of a perforating well of a deep sandstone reservoir. The method for predicting the sand production pressure difference profile of the perforating well of the deep sandstone reservoir comprises the following steps: calculating rock mechanical parameter values through target well logging data, and acquiring a rock mechanical parameter profile along a well trajectory; calculating the distribution of the ground stress field of the target well, and acquiring a three-dimensional main stress value profile along the well trajectory; calculating the ground stress values under different stratum pressure values according to the change of the oil reservoir pressure; establishing a well circumferential stress distribution model; calculating the stress distribution around the well at each point of the well section; introducing the well circumferential stress values of all points of the well section into a rock destruction criterion, and calculating a critical sand production differential pressure profile of a target well to obtain a sand production well section; and calculating the magnitude of the ground stress values under different reservoir pressures, and bringing the ground stress values into a sand production pressure difference model to calculate the sand production critical pressure difference of each production stage. The invention solves the problem that the method for predicting the sand production pressure difference profile in the prior art is unreasonable.
Description
Technical Field
The invention relates to the technical field of petroleum and natural gas development, in particular to a deep sandstone reservoir perforated well sand production differential pressure profile prediction method.
Background
The deep ultrahigh pressure high-yield sandstone reservoir has huge reserves, extremely high capacity and wide exploration and development prospects. However, due to the large buried depth, high reservoir temperature and high formation pressure of the oil reservoir, once sand is produced, the problems of sand accumulation, liquid accumulation, tubular column damage, ground equipment damage and the like in a shaft seriously affect the safe production, and simultaneously cause high sand prevention cost and huge economic loss. In order to ensure normal and efficient exploitation of a high-yield oil reservoir, it is one of necessary works to make a reasonable production scheme according to a sand production pressure difference prediction result. Generally, sand production occurs in loose sandstone oil and gas reservoirs with large rock porosity, low cementation degree and small rock strength, but recent production practices similar to deep ultrahigh-pressure sandstone oil reservoirs show that sand production risks also exist in the production process of the oil reservoirs, the oil reservoirs are deeply buried, the compaction effect of overburden rock pressure on reservoir rocks is large, the rocks are compact, sand production is difficult to achieve through general experience sand production prediction methods, and a reasonable sand production differential pressure profile prediction method aiming at the oil reservoir characteristics is lacked at present.
Therefore, the problem that the method for predicting the sand production differential pressure profile is unreasonable exists in the prior art.
Disclosure of Invention
The invention mainly aims to provide a method for predicting a sand production pressure difference profile of a perforating well of a deep sandstone reservoir, so as to solve the problem that the method for predicting the sand production pressure difference profile in the prior art is unreasonable.
In order to achieve the above object, according to an aspect of the present invention, there is provided a deep sandstone reservoir perforating well sand production pressure difference profile prediction method, including: calculating rock mechanical parameter values through target well logging data, and acquiring a rock mechanical parameter profile along a well trajectory; calculating the distribution of the ground stress field of the target well, and acquiring a three-dimensional main stress value profile along the well trajectory; calculating the ground stress values under different formation pressure values according to the change of the oil reservoir pressure; establishing a well circumferential stress distribution model; calculating the stress distribution around the well at each point of the well section; introducing the well circumferential stress values of all points of the well section into a rock failure criterion, and calculating a critical sand production differential pressure profile of a target well to obtain a sand production well section; and calculating the magnitude of the ground stress values under different reservoir pressures, and bringing the ground stress values into a sand production pressure difference model to calculate the sand production critical pressure difference of each production stage.
Further, when rock mechanical parameter values are calculated through target well logging data, natural gamma, density, sound wave, resistivity and hole diameter parameter values obtained through target well reservoir section logging are selected to calculate the rock mechanical parameters of the target stratum.
Further, in the process of calculating the distribution of the ground stress field of the target well and acquiring the three-way main stress value profile along the well trajectory, the overburden pressure of the target well is obtained by integrating density logging parameters, and the calculation formula is as follows:
wherein σ v Is the total vertical stress in units of MPa, D TV Is the vertical depth, the unit m, g is the acceleration of gravity, O is the offset value, ρ b Is the bulk density in kg/m 3 。
Further, in the process of calculating the distribution of the ground stress field of the target well and acquiring the three-dimensional main stress value profile along the well trajectory, the relationship between the horizontal maximum main stress and the horizontal minimum main stress of the target well is as follows:
wherein σ h To minimum level of principal stress, σ H At maximum level principal stress, α is the effective stress coefficient, biot coefficient, μ is Poisson's ratio, P p As pore pressure, E is the static Young's modulus, ξ h Strain in the direction of least principal stress, ξ H Is the strain in the direction of the maximum principal stress.
Further, after the well circumferential stress distribution model is established, the rock mechanical parameter values and the ground stress values of the target well along the well trajectory are brought into the established well circumferential stress distribution model to calculate the well circumferential stress distribution of each point of the well section.
Further, the built well circumference stress distribution model comprises a perforated shaft stress distribution model, a perforated shaft fluid seepage additional stress and production pressure difference stress distribution model, an oil well fluid dragging force stress model in the production process and a fluid dragging force stress distribution model at the wall of a perforated hole.
Further, the stress distribution model of the perforating shaft is as follows:
σ xx ，σ yy ，σ zz respectively, the normal stress component in the coordinate system (x, y, z) in MPa, τ xy ，τ yz ， τ xz -the components of the shear stress in the coordinate system (x, y, z), respectively, in MPa.
Further, the stress distribution model of the fluid seepage additional stress and the production differential pressure of the perforating shaft is as follows:
further, the stress model of the oil well fluid drag force in the production process is as follows:
further, the stress distribution model at the perforation hole wall by the fluid drag force is as follows:
furthermore, the well circumferential stress values of all points of the well section are brought into the rock failure criterion, the critical sand production pressure difference profile of the target well is calculated, when the sand production well section is obtained, all the stresses in the formula (7) are calculated, and the maximum stress sigma is used 1 Minimum response σ 3 Substituting into the M-C failure criterion to obtain the critical flow pressure P w 。
Further, the critical flow pressure P is obtained w Then, calculating the formation pressure and the ground stress field size in different production stages of the oil well, and obtaining the critical sand production pressure difference under different formation pressures through a formula (7) and a formula (8), wherein the formula (8) can be expressed as:
also, the critical sand production differential pressure at different formation pressures can be expressed as equation (9):
ΔP＝P w -P p formula (9)
By applying the technical scheme of the invention, the method for predicting the sand production differential pressure profile of the deep sandstone reservoir perforation well comprises the following steps: calculating rock mechanical parameter values through target well logging data, and acquiring a rock mechanical parameter profile along a well trajectory; calculating the distribution of the ground stress field of the target well, and acquiring a three-dimensional main stress value profile along the well trajectory; calculating the ground stress values under different formation pressure values according to the change of the reservoir pressure; establishing a well circumferential stress distribution model; calculating the stress distribution around the well at each point of the well section; introducing the well circumferential stress values of all points of the well section into a rock failure criterion, and calculating a critical sand production differential pressure profile of a target well to obtain a sand production well section; and calculating the magnitude of the ground stress values under different reservoir pressures, and bringing the ground stress values into a sand production pressure difference model to calculate the sand production critical pressure difference of each production stage.
The method is based on logging data, considers various characteristic influence factors, can more accurately predict the sand production critical pressure difference profile of the oil reservoir perforation well, reasonably avoids the easy sand production well section and provides a theoretical basis for recommending the reasonable production pressure difference.
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The accompanying drawings, which are incorporated in and constitute a part of this application, illustrate exemplary embodiments of the invention and, together with the description, serve to explain the invention and are not intended to limit the invention. In the drawings:
FIG. 1 is a technical route diagram in the method for predicting the sand production critical pressure difference profile of a deep ultrahigh pressure sandstone reservoir perforating well provided by the embodiment of the invention.
FIG. 2 is a comprehensive diagram of the rock mechanical parameters of a reservoir at a target well section in the prediction method of the sand production critical pressure difference profile of the deep ultrahigh pressure sandstone reservoir perforating well provided by the embodiment of the invention.
Fig. 3 is a comprehensive diagram of the ground stress profile of a target well in the method for predicting the sand production critical pressure difference profile of a deep ultrahigh pressure sandstone reservoir perforating well provided by the embodiment of the invention.
Fig. 4 is a sand production pressure difference prediction diagram of a target well reservoir section in the deep ultra-high pressure sandstone reservoir perforating well sand production critical pressure difference profile prediction method provided by the embodiment of the invention, without considering fluid drag force.
Fig. 5 is a diagram for predicting the sand production pressure difference of a reservoir section of a target well in the method for predicting the sand production critical pressure difference profile of the perforating well of the deep ultrahigh-pressure sandstone reservoir.
Fig. 6 is a sand production critical pressure difference diagram corresponding to different formation pressures of a target well in the deep ultra-high pressure sandstone reservoir perforating well sand production critical pressure difference profile prediction method provided by the embodiment of the invention at different production stages.
Detailed Description
It should be noted that the embodiments and features of the embodiments in the present application may be combined with each other without conflict. The present invention will be described in detail below with reference to the embodiments with reference to the attached drawings.
It is noted that, unless otherwise indicated, all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this application belongs.
In the present invention, unless stated to the contrary, use of the terms of orientation such as "upper, lower, top, bottom" or the like, generally refer to the orientation as shown in the drawings, or to the component itself in a vertical, perpendicular, or gravitational orientation; likewise, for ease of understanding and description, "inner and outer" refer to the inner and outer relative to the profile of the components themselves, but the above directional words are not intended to limit the invention.
In order to solve the problem that a sand production pressure difference profile prediction method in the prior art is unreasonable, the application provides a deep sandstone reservoir perforating well sand production pressure difference profile prediction method.
As shown in fig. 1 to 6, the method for predicting the sand production pressure difference profile of the deep sandstone reservoir perforation well in the application comprises the following steps: calculating rock mechanical parameter values through target well logging data, and acquiring a rock mechanical parameter profile along a well trajectory; calculating the distribution of the ground stress field of the target well, and acquiring a three-dimensional main stress value profile along the well trajectory; calculating the ground stress values under different stratum pressure values according to the change of the oil reservoir pressure; establishing a well circumferential stress distribution model; calculating the stress distribution around the well at each point of the well section; introducing the well circumferential stress values of all points of the well section into a rock destruction criterion, and calculating a critical sand production differential pressure profile of a target well to obtain a sand production well section; and calculating the magnitude of the ground stress values under different reservoir pressures, and bringing the ground stress values into a sand production pressure difference model to calculate the sand production critical pressure difference of each production stage. The method is based on logging data, considers various characteristic influence factors, can more accurately predict the sand production critical pressure difference profile of the oil reservoir perforated well, reasonably avoids the easy sand production well section and provides a theoretical basis for recommending the reasonable production pressure difference.
In one embodiment of the application, the method for predicting the sand production pressure difference profile of the deep sandstone reservoir perforation well mainly comprises the following steps:
(A) Calculating the size of a rock mechanical parameter value through target well logging data, and acquiring a rock mechanical parameter profile along a well trajectory;
(B) Calculating the distribution of the ground stress field of the target well, and acquiring a three-dimensional main stress value profile along the well trajectory;
(C) Changing the ground stress field along with the attenuation of the oil reservoir pressure in the oil reservoir production process, and calculating the magnitude of the ground stress value under different stratum pressure values;
(D) Substituting the rock mechanical parameter value and the ground stress value of the target well along the well trajectory into the established well circumferential stress distribution model, and calculating the well circumferential stress distribution of each point of the well section;
(E) Introducing the well circumferential stress values of all points of the well section into a rock destruction criterion, calculating a critical sand production differential pressure profile of a target well, and judging to obtain the well section which is most prone to sand production;
(F) And calculating the magnitude of the ground stress values under different reservoir pressures, and bringing the ground stress values into a sand production pressure difference model to calculate the sand production critical pressure difference of each production stage.
The method is based on rock mechanical parameters and ground stress parameters, comprehensively considers the influence of factors such as fluid drag force, formation pressure failure and ground stress change on sand production, predicts the critical sand production differential pressure profile of the deep ultrahigh pressure sandstone reservoir, solves the problem of difficult prediction of the critical production differential pressure of sand production of the gas reservoir, and provides reference for sand control measures in oil well production.
And in the step A, natural gamma, density, sound wave, resistivity and hole diameter parameter values obtained by logging in the reservoir section of the target well are selected to calculate rock mechanics parameters of the target stratum. If the logging data is short of transverse wave data, the transverse wave velocity can be obtained by data conversion such as formation longitudinal wave velocity:
the calculation formula of Young's modulus E is shown in (11):
in the formula (11) (. Rho) b The density log is kg/m3.
The dynamic Poisson ratio calculation formula is shown as (12):
the compressive strength calculation formula is shown as (13):
S c ＝E[0.008V sh +0.0045(1-V sh )]formula (13)
In the formula (13), V sh The shale content can be calculated by a natural gamma curve.
The reservoir rock shear modulus formula is:
G＝ρV s 2 formula (14)
In formula (14), G is the shear modulus, GPa; ρ is the formation density (which can be obtained from the density curve), g/cm3.
The calculation formula of the friction coefficient in the reservoir rock is as follows:
in step B, in the preferred embodiment of the present invention, the vertical principal stress, i.e., overburden pressure, is typically determined by integrating the density logging parameters. The calculation formula is shown as (1):
wherein σ v Is the total vertical stress in units of MPa, D TV Vertical depth, in units of m, g, acceleration of gravity, O, offset, ρ b Is the bulk density in kg/m 3 。
In step B, in the preferred embodiment of the present invention, the calculation formulas (2) and (3) of the horizontal maximum and minimum principal stresses are preferably combined with the calculation formula of the porous elasticity:
wherein σ h At minimum level of principal stress, σ H At maximum level principal stress, α is the effective stress coefficient, i.e., biot coefficient, μ is Poisson's ratio, P p As pore pressure, E is the static Young's modulus, ξ h Strain, ξ, in the direction of least principal stress H Strain in the direction of maximum principal stress.
In the step C, the reservoir pressure is attenuated along with the exploitation of the oil-gas reservoir, the overburden rock pressure is jointly borne by the rock framework and the rock fluid, when the overburden rock pressure of the reservoir is assumed to be unchanged, the pressure applied to the rock framework is larger and larger along with the reduction of the pore pressure of the stratum, the bearing capacity of the rock under a specific burial depth is certain, and when the effective stress borne by the rock exceeds the bearing capacity of the reservoir rock, the rock is damaged. Therefore, during the production process of an oil reservoir, a stratum undergoes a series of complex geomechanical processes such as elastic compaction, plastic deformation, new microcrack formation and closing or opening of existing cracks, the vertical principal stress changes are ignored, and the maximum and minimum horizontal principal stresses change simultaneously and can be represented as:
wherein:
in the formula:
P i original pressure, MPa; is the load factor, P c Is the current formation pressure, MPa.
In the step D, the stress distribution calculation model of the perforating shaft can be expressed as (4):
σ xx ，σ yy ，σ zz -respectively the normal stress component in MPa, τ in the coordinate system (x, y, z) xy ，τ yz ， τ xz -the components of the shear stress in the coordinate system (x, y, z), respectively, in MPa.
Further, the stress distribution model of the fluid seepage additional stress and the production differential pressure of the perforating shaft is as follows:
further, the stress model of the drag force of the oil well fluid in the production process is as follows:
further, the stress distribution model at the perforation wall by the fluid drag force is as follows:
introducing the well circumferential stress values of all points of the well section into the rock failure criterion, calculating the critical sand production differential pressure profile of the target well, calculating all the stresses in the formula (7) when the sand production well section is obtained, and adding the maximum stress sigma 1 Minimum response σ 3 The critical flow pressure P is obtained by substituting into the M-C damage criterion w 。
At the critical flow pressure P w Then, calculating the formation pressure and the magnitude of the ground stress field in different production stages of the oil well, and obtaining the critical sand production pressure difference under different formation pressures through a formula (7) and a formula (8), wherein the formula (8) can be expressed as follows:
also, the critical sand production differential pressure at different formation pressures can be expressed as equation (9):
ΔP＝P w -P p formula (9)
In one particular embodiment of the present application:
(1) Establishing a rock mechanical parameter profile of the target well;
selecting logging data of natural gamma, density, sound wave, resistivity and the like of a reservoir section 5200-5700 m of a target well X, calculating dynamic rock mechanical parameters (parameters such as compressive strength, young modulus, dynamic Poisson ratio, internal friction coefficient and the like) of a target stratum by adopting a parameter calculation formula according with reservoir characteristics, and finally obtaining a comprehensive rock mechanical parameter profile of the target well, wherein in the comprehensive rock mechanical parameter profile of the well reservoir, the uniaxial compressive strength is 73MPa on average, the Young modulus is 33GPa on average, the Poisson ratio is 0.24 on average, the internal friction coefficient is 0.74 on average, and the porosity is 0.1 on average, as shown in an attached diagram 2.
(2) Establishing a ground stress parameter profile of a target well;
the vertical principal stress is determined by integrating a density log, the calculation formula is shown as (2), and the horizontal maximum and minimum principal stresses are preferably combined with the porous elasticity calculation formulas (3) and (4): calculating to obtain a ground stress profile according to site construction data, a logging curve and a core experiment, wherein as shown in fig. 3, the average of the horizontal section stratum pressure gradient is 0.024MPa/m, the horizontal section stratum pressure is about 133MPa, the average of the vertical stress gradient is 0.26MPa/m, and the vertical stress is about 146 MPa; the minimum horizontal principal stress gradient is averagely 0.025MPa/m, and the minimum horizontal principal stress is about 139 MPa; the average of the maximum horizontal main stress gradient is 0.028MPa/m, and the average of the maximum horizontal main stress is about 150 MPa.
(3) Establishing a critical production pressure difference profile and an easily-produced sand well section of a deep ultrahigh pressure sandstone reservoir perforating well;
and substituting the rock mechanical parameters and the ground stress parameter data into a stress distribution model and a molar coulomb criterion at the perforation hole wall considering the fluid dragging force, and solving a critical flow pressure and a corresponding critical sand production differential pressure profile. The well deviation direction of the target well is about 90 degrees, the stratum pressure is high, the yield is high, the dragging force of fluid at the position of the perforation is extremely strong, the perforation density is 16 holes/m, the thickness of a perforated oil layer is 1m, the radius of the perforation is 5mm, the length of a cement ring outside the perforation is 0.95m, the permeability around the perforation is 65mD, the skin coefficient is 1.5, and the thickness of the oil layer is 11m. The profile of the sand production critical differential pressure without taking into account drag force is shown in fig. 4. The sand production always occurs at the place where the rock is firstly damaged, namely the minimum value of the critical pressure difference along the well depth section is the sand production critical pressure difference value of the well. The minimum critical sand producing pressure difference of 5200-5700 m horizontal well section is 43.9MPa. By adopting the perforation critical sand production critical differential pressure model established by the invention after considering the dragging force of the well hole, the sand production critical differential pressure profile when the target well is perforated along the maximum horizontal principal stress is calculated and is shown in figure 5, at the moment, the minimum critical sand production differential pressure of the well is about 39.6MPa when a perforation completion mode is adopted, and the critical sand production differential pressure is reduced by about 4.3MPa compared with the critical sand production differential pressure when the dragging force is not considered. And the sand production critical pressure difference near the well sections of 5210m, 5420m and the like is small, so that the positions with the low sand production critical pressure difference can be avoided for ensuring the stability of the perforation pore passage of the perforation well.
(4) Predicting the sand production pressure difference of the target well under different stratum pressures;
with the attenuation of the reservoir pressure in the production process of the reservoir, the ground stress field is changed, the ground stress values under different formation pressure values are calculated, the original formation pressure of the target reservoir is 133MPa, the formation pressure is exhausted under the condition that the mechanical parameters of the rock are the same at the same position of the reservoir, and the overlying ground stress is not changed, the mechanical parameters of the rock are analyzed by using the single point, the perforation direction along the direction of the maximum main stress is taken as an example, and the change rule of the ground stress and the change rule of the sand outlet critical pressure difference of the perforation hole are analyzed, as shown in FIG. 6. As the formation pressure collapses, both its maximum and minimum levels of principal stress decrease. And the critical pressure difference of the sand produced by perforating the horizontal well is calculated by a horizontal well perforation critical pressure difference model, and the critical pressure difference of the sand produced by perforating the horizontal well is reduced to 4.3MPa from 39.6MPa along with the reduction of the maximum horizontal main stress and the minimum horizontal main stress.
From the above description, it can be seen that the above embodiments of the present invention achieve the following technical effects that the present invention performs the prediction of the critical sand production pressure difference profile of the deep ultra-high pressure sandstone reservoir based on the rock mechanical parameters and the ground stress parameters and comprehensively considering the influence of the factors such as the fluid drag force, the formation pressure failure and the ground stress change on the sand production, so as to solve the problem of difficult prediction of the critical sand production pressure difference of the gas reservoir, and provide a reference for the sand control measures in the oil well production.
It is to be understood that the above-described embodiments are only a few, but not all, embodiments of the present invention. All other embodiments obtained by a person of ordinary skill in the art based on the embodiments of the present invention without making any creative efforts shall fall within the protection scope of the present invention.
It is noted that the terminology used herein is for the purpose of describing particular embodiments only and is not intended to be limiting of example embodiments according to the present application. As used herein, the singular forms "a", "an", and "the" are intended to include the plural forms as well, and it should be understood that when the terms "comprises" and/or "comprising" are used in this specification, they specify the presence of stated features, steps, operations, devices, components, and/or combinations thereof, unless the context clearly indicates otherwise.
It should be noted that the terms "first," "second," and the like in the description and claims of this application and in the accompanying drawings are used for distinguishing between similar elements and not necessarily for describing a particular sequential or chronological order. It is to be understood that the data so used is interchangeable under appropriate circumstances such that the embodiments of the application described herein are capable of operation in other sequences than those illustrated or described herein.
The above description is only a preferred embodiment of the present invention and is not intended to limit the present invention, and various modifications and changes may be made by those skilled in the art. Any modification, equivalent replacement, or improvement made without departing from the spirit and principle of the present invention shall fall within the protection scope of the present invention.
Claims (10)
1. A deep sandstone reservoir perforating well sand production pressure difference profile prediction method is characterized by comprising the following steps:
calculating rock mechanical parameter values through target well logging data, and acquiring a rock mechanical parameter profile along a well trajectory;
calculating the distribution of the ground stress field of the target well, and acquiring a three-way main stress value profile along the well trajectory;
calculating the ground stress values under different formation pressure values according to the change of the oil reservoir pressure;
establishing a well circumferential stress distribution model;
calculating the stress distribution around the well at each point of the well section;
substituting the well circumferential stress values of all points of the well section into a rock failure criterion, calculating a critical sand production differential pressure profile of the target well, and obtaining a sand production well section;
and calculating the magnitude of the ground stress values under different reservoir pressures, and bringing the ground stress values into a sand production pressure difference model to calculate the sand production critical pressure difference of each production stage.
2. The method for predicting the deep sandstone reservoir perforated well sand production pressure difference profile according to claim 1, wherein when rock mechanics parameter values are calculated through the target well logging data, the natural gamma, density, sound wave, resistivity and hole diameter parameter values obtained through logging of the reservoir section of the target well are selected to calculate the rock mechanics parameters of the target stratum.
3. The deep sandstone reservoir perforated well sand production pressure difference profile prediction method according to claim 1, characterized in that after a well circumferential stress distribution model is established, rock mechanical parameter values and ground stress values of the target well along a well trajectory are brought into the established well circumferential stress distribution model to calculate the well circumferential stress distribution of each point of a well section.
4. The deep sandstone reservoir perforated well sand production differential pressure profile prediction method of claim 3, wherein the built well-periphery stress distribution model comprises a perforated well shaft stress distribution model, a perforated well shaft fluid seepage additional stress and production differential pressure stress distribution model, an oil well fluid dragging force stress model in the production process, and a fluid dragging force stress distribution model at the perforated well wall.
5. The deep sandstone reservoir perforated well sand production pressure difference profile prediction method of claim 4, wherein the perforated well bore stress distribution model is as follows:
σ xx ，σ yy ，σ zz -respectively the normal stress component in MPa, τ in the coordinate system (x, y, z) xy ，τ yz ，τ xz -the components of the shear stress in the coordinate system (x, y, z), respectively, in MPa.
6. The deep sandstone reservoir perforated well sand production pressure difference profile prediction method of claim 5, wherein the stress distribution model of the fluid seepage additional stress and the production pressure difference of the perforated well bore is as follows:
7. the method for predicting the sand production pressure difference profile of the deep sandstone reservoir perforated well according to claim 6, wherein the stress model of the drag force of the oil well fluid in the production process is as follows:
8. the deep sandstone reservoir perforated well sand production differential pressure profile prediction method of claim 7, wherein the stress distribution model at the wall of the fluid drag force perforated well is:
9. the method of predicting the sand production pressure difference profile of a deep sandstone reservoir perforated well according to claim 8, wherein the method comprises the steps of calculating the critical sand production pressure difference profile of the target well by substituting the well circumferential stress values of all points of the well section into a rock failure criterion, calculating each stress in the formula (7) when obtaining the sand production well section, and calculating the maximum stress sigma 1 Minimum response σ 3 Substituting into the M-C failure criterion to obtain the critical flow pressure P w 。
10. The method of predicting the sand production pressure difference profile of a deep sandstone reservoir perforated well according to claim 9, wherein the critical flow pressure P is obtained w Then, calculating the formation pressure and the ground stress field size in different production stages of the oil well, and obtaining the critical sand production pressure difference under different formation pressures through a formula (7) and a formula (8), wherein the formula (8) can be expressed as:
also, the critical sand production differential pressure at different formation pressures can be expressed as equation (9):
ΔP＝P w -P p equation (9).
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