CN114510853B - Well type optimization design method based on fracture-cavity type oil reservoir three-dimensional ground stress field distribution - Google Patents
Well type optimization design method based on fracture-cavity type oil reservoir three-dimensional ground stress field distribution Download PDFInfo
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- 238000005457 optimization Methods 0.000 title claims abstract description 20
- 238000002347 injection Methods 0.000 claims abstract description 37
- 239000007924 injection Substances 0.000 claims abstract description 37
- 238000004891 communication Methods 0.000 claims abstract description 24
- 239000007788 liquid Substances 0.000 claims abstract description 24
- 238000004364 calculation method Methods 0.000 claims description 6
- 238000004088 simulation Methods 0.000 claims description 3
- 238000004519 manufacturing process Methods 0.000 abstract description 13
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- 239000003129 oil well Substances 0.000 abstract description 3
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- 206010017076 Fracture Diseases 0.000 description 54
- 208000010392 Bone Fractures Diseases 0.000 description 49
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- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 description 7
- 239000012530 fluid Substances 0.000 description 6
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- 238000010586 diagram Methods 0.000 description 4
- 239000007789 gas Substances 0.000 description 4
- 239000001257 hydrogen Substances 0.000 description 4
- 229910052739 hydrogen Inorganic materials 0.000 description 4
- -1 hydrogen ions Chemical class 0.000 description 4
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Abstract
According to the well type optimization design method based on the three-dimensional ground stress field distribution of the fracture-cavity oil reservoir, a shaft azimuth angle is set according to the ground stress field distribution condition and the fracture-cavity production shape, a plurality of shaft well bevels are selected, liquid injection is simulated under the same condition after three-dimensional ground stress field models of reservoirs with shafts are respectively formed, fracture-cavity communication coefficients under the selected shaft well bevels are calculated according to the number of communicated natural cracks and the communicated natural holes after liquid injection is simulated, the well bevel angle corresponding to the three-dimensional ground stress field model of the reservoir with the shaft with the largest fracture-cavity communication coefficient value is the optimized optimal shaft well bevel angle, good guiding effect is achieved on site construction design, improvement of reservoir transformation effects is facilitated, and oil well productivity is released.
Description
Technical Field
The invention relates to the technical field of development of fracture-cavity oil reservoirs, in particular to a well type optimal design method based on three-dimensional ground stress field distribution of the fracture-cavity oil reservoir.
Background
The carbonate reservoir resources in China are rich, and fracture-cavity type is mainly used. The exploitation of the complex fracture-cavity carbonate oil reservoir is an important technical field of exploration and development of oil and gas fields in China, the development of natural fractures and corrosion holes of the fracture-cavity carbonate oil reservoir is realized, and the acid fracturing transformation is to communicate with the development bodies of the natural fractures and corrosion holes in the oil reservoir and form a complex fracture network with certain diversion energy, so that the oil well construction and production are realized. The well type selection of the fracture-cavity type carbonate reservoir is significant for the development of the reservoir, the research on the well type optimization design method of the fracture-cavity type reservoir is very little at present, and the exploitation effect of the fracture-cavity type reservoir is poor due to the fact that the well type selection is not proper.
The invention patent of application number CN201810208667.9 discloses a fracture-cavity oil reservoir space structure injection well pattern optimization design method, which specifically discloses the following steps: s1): determining a plurality of initial injection and production schemes according to the positions of the wells or the types of the reservoirs of the wells; s2): respectively calculating the communication degree between the injection and production wells of each initial injection and production scheme; s3): according to the communication degree between the injection and production wells of each initial injection and production scheme, respectively calculating the coefficient of the communication degree between the injection and production wells; s4): and selecting the initial injection and production scheme with the smallest coefficient of the base as the final injection and production scheme. The fracture-cavity oil reservoir space structure injection well pattern optimization design method is only an optimization selection method of a water injection well pattern, and well optimization data of an oil production well can not be obtained according to the distribution condition of a ground stress field and fracture-cavity production.
Disclosure of Invention
The invention provides a well type optimization design method based on three-dimensional ground stress field distribution of a fracture-cavity type oil reservoir.
The technical scheme of the invention is as follows:
a well type optimization design method based on fracture-cavity oil reservoir three-dimensional ground stress field distribution comprises the following steps:
S1, collecting reservoir ground stress field distribution data, natural fracture occurrence data and karst cave distribution data of a fracture-cave type oil reservoir, and establishing a reservoir three-dimensional ground stress field model with karst cave and natural fracture in a simulation mode, wherein the reservoir ground stress field distribution data comprise ground stress azimuth data and ground stress size data, and the reservoir ground stress field distribution data of the fracture-cave type oil reservoir at least comprise horizontal maximum ground stress size and azimuth, horizontal minimum ground stress size and azimuth and vertical stress size and azimuth;
S2, setting a shaft azimuth according to azimuth data and size data of horizontal ground stress, selecting a plurality of shaft well bevels within a range of-90 degrees to 90 degrees, and respectively adding a shaft model into the same three-dimensional ground stress field model of the reservoir with the karst cave and the natural fracture to obtain a three-dimensional ground stress field model of the reservoir with the shaft;
S3, simulating liquid injection into a three-dimensional ground stress field model of the reservoir with the shaft by adopting the same liquid injection mode and liquid injection amount, and calculating a fracture-hole communication coefficient omega under each selected shaft oblique angle according to the number of communicated natural fractures and the number of communicated natural holes after simulated liquid injection;
S4, comparing the fracture-cavity communication coefficients under the selected wellbore well angles to obtain the optimized optimal wellbore well angles and the optimized wellbore azimuth angles.
Preferably, in S3, the calculation formula of the slot communication coefficient Ω is Ω=0.5×n+0.75×m, where n is the number of natural slots communicated after the simulated injection, and m is the number of natural holes communicated after the simulated injection.
Preferably, in the step S2, a shaft azimuth is set according to azimuth data and magnitude data of the horizontal ground stress, specifically, an azimuth of the horizontal minimum ground stress is obtained according to the azimuth data and magnitude data of the horizontal ground stress, and the set shaft azimuth is the azimuth of the horizontal minimum ground stress.
Preferably, in the step S4, when the fracture-cavity communication coefficient Ω value under each selected wellbore well oblique angle is the largest, the corresponding well oblique angle is the optimized optimal wellbore well oblique angle.
Preferably, the natural fracture occurrence data comprises the number of natural fractures and distribution situation data of the natural fractures in a reservoir ground stress field; the karst cave distribution data comprise the number of karst cave and distribution situation data of the karst cave in a reservoir ground stress field.
Preferably, the reservoir ground stress field distribution data of the fracture-cavity oil reservoir at least comprises the magnitude and the azimuth of horizontal maximum ground stress, the magnitude and the azimuth of horizontal minimum ground stress and the magnitude and the azimuth of vertical stress.
Compared with the prior art, the invention has the advantages that: according to the well type optimization design method based on the three-dimensional ground stress field distribution of the fracture-cavity oil reservoir, a shaft azimuth angle is set according to the ground stress field distribution condition and the fracture-cavity production shape, a plurality of shaft well bevels are selected, liquid injection is simulated under the same condition after three-dimensional ground stress field models of reservoirs with shafts are respectively formed, fracture-cavity communication coefficients under the selected shaft well bevels are calculated according to the number of communicated natural cracks and the communicated natural holes after liquid injection is simulated, the well bevel angle corresponding to the three-dimensional ground stress field model of the reservoir with the shaft with the largest fracture-cavity communication coefficient value is the optimized optimal shaft well bevel angle, good guiding effect is achieved on site construction design, improvement of reservoir transformation effects is facilitated, and oil well productivity is released.
Drawings
FIG. 1 is a flow chart of a well type optimization design method based on fracture-cavity oil reservoir three-dimensional ground stress field distribution;
FIG. 2 is a plane stress diagram obtained according to reservoir ground stress field distribution data in a well optimization design method based on fracture-cavity oil reservoir three-dimensional ground stress field distribution, wherein the abscissa is the length of a model in the horizontal direction and the ordinate is the width of the model in the horizontal direction;
FIG. 3 is a vertical section stress diagram obtained according to reservoir ground stress field distribution data in the well type optimization design method based on fracture-cavity type oil reservoir three-dimensional ground stress field distribution, wherein the abscissa is the vertical direction length of a model, and the ordinate is the vertical direction width of the model.
Detailed Description
In order that the invention may be readily understood, a more particular description of the invention will be rendered by reference to specific embodiments that are illustrated below.
A well type optimization design method based on fracture-cavity oil reservoir three-dimensional ground stress field distribution is shown in a flow chart as shown in figure 1, and comprises the following steps:
S1, collecting reservoir stratum ground stress field distribution data, natural fracture occurrence data and karst cave distribution data of a fracture-cave type oil reservoir, simulating and establishing a reservoir stratum three-dimensional ground stress field model with karst cave and natural fracture, wherein,
The plane stress diagram obtained according to the reservoir ground stress field distribution data is shown in fig. 2, wherein the abscissa is the length of the model in the horizontal direction, and the ordinate is the width of the model in the horizontal direction. As can be seen from fig. 2, the horizontal maximum ground stress is 140MPa, the azimuth angle thereof is in the north direction, the horizontal minimum ground stress is 120MPa, and the azimuth angle thereof is in the east direction.
The vertical section stress diagram obtained according to the reservoir ground stress field distribution data is shown in fig. 3, and as can be seen from fig. 3, the vertical stress is 170MPa, and the azimuth angle is the vertical direction.
S2, setting the azimuth angle of the shaft to be forward direction according to azimuth data of horizontal minimum ground stress, and selecting-90 degrees, -30 degrees, 0 degrees, 30 degrees and 90 degrees as shaft well angles within the range of-90 degrees to 90 degrees;
S3, simulating liquid injection into the shaft by adopting the same liquid injection mode and liquid injection amount according to the selected shaft well oblique angle and the set shaft azimuth angle, and acquiring the number n of communicated natural cracks and the number m of communicated natural holes after simulated liquid injection.
When the well inclination angle of the shaft is-90 degrees, the number of natural cracks communicated after simulated liquid injection is 8, and the number of natural holes communicated is 1; when the well inclination angle of the shaft is-30 degrees, the number of natural cracks communicated after simulated liquid injection is 8, and the number of natural holes communicated is 1; when the well inclination angle of the shaft is 0 degree, the number of communicated natural cracks after simulated liquid injection is 6, and the number of communicated natural holes is 0; when the well inclination angle of the shaft is 30 degrees, the number of natural cracks communicated after simulated injection is 8, and the number of natural holes communicated is 1; when the well inclination angle of the shaft is 90 degrees, the number of communicated natural cracks after simulated injection is 9, and the number of communicated natural holes is 1;
According to the calculation formula Ω=0.5×n+0.75×m of the fracture-cavity communication coefficient Ω, the fracture-cavity communication coefficient is 4.75 when the wellbore inclination angle is-90 °; when the well bevel angle of the shaft is-30 degrees, the joint hole communication coefficient is 4.75; when the well inclination angle of the shaft is 0 DEG, the joint hole communication coefficient is 3; when the well bevel angle of the shaft is 30 degrees, the joint hole communication coefficient is 4.75; when the well bevel angle of the shaft is 90 degrees, the joint hole communication coefficient is 5.25;
S4, comparing the seam hole communication coefficients under the well angles of the selected well bores to obtain the seam hole communication coefficient omega value of 5.25 at most under the well angles of-90 degrees, -30 degrees, 0 degrees, 30 degrees and 90 degrees, wherein the corresponding well angle is 90 degrees, so that the optimal well angle obtained through optimization is 90 degrees, and the optimal well angle is in the forward direction.
Preferably, in step S1 of the present invention, the collecting the reservoir ground stress field distribution data, the natural fracture occurrence data and the karst cave distribution data of the fracture-cave type oil reservoir simulates and builds a reservoir three-dimensional ground stress field model with karst cave and natural fracture, which comprises the following specific steps:
step one, acquiring reservoir ground stress field distribution data of a fracture-cavity type oil and gas reservoir, and simulating a reservoir three-dimensional ground stress field model in finite element processing software;
Step two, karst cave distribution data in a fracture-cave type oil and gas reservoir are obtained, and the three-dimensional ground stress field of the step one is endowed with the karst cave distribution data, so that a reservoir three-dimensional ground stress field model with karst cave is obtained;
And thirdly, acquiring natural fracture occurrence data in the fracture-cavity type oil and gas reservoir, and endowing the natural fracture occurrence data into the three-dimensional ground stress field with the karst cavity in the second step to obtain a three-dimensional ground stress field model of the reservoir with the karst cavity and the natural fracture.
Preferably, in step S3 of the present invention, before simulating injection into a three-dimensional ground stress field model of a reservoir with a well bore, a two-dimensional mathematical model is further added into the three-dimensional ground stress field model of the reservoir with a well bore, so that the three-dimensional ground stress field model of the reservoir with a well bore can perform acidification numerical simulation, and the specific steps are as follows:
Step one, a double-scale mathematical model is established, wherein the double-scale mathematical model comprises a Darcy scale model and a pore scale model, and the pore scale model provides parameter support for the Darcy scale model.
The double-scale mathematical model is used in a reservoir geological model containing natural cracks, the flow of acid liquor in the natural cracks and the reaction of the acid liquor with carbonate are calculated, the flow path of the acid liquor with the hole finding and acidizing along the cracks is simulated, and the simulated flow path of the acid liquor with the hole finding and acidizing along the cracks is used for the acidizing engineering design of the carbonate reservoir.
(A-a) establishing a darcy scale model: the darcy scale model is used for describing a model of a centimeter-level to micrometer-level porous medium, and the acid liquor is darcy seepage in the centimeter-level to micrometer-level porous medium.
(1) Acid flow in a matrix
The acid liquor is injected into the stratum at a certain speed, and hydrogen ions in the acid liquor react from mass transfer in the pore medium fluid to the surface of the carbonate rock under the macroscopic motion (convection) and concentration gradient (diffusion) in the fluid, so that the porosity and permeability of the stratum are changed. The flow of acid in the matrix formation is governed by darcy's law:
the fluid pressure profile is governed by the equation of continuity of the incompressible fluid:
The concentration distribution of hydrogen ions in the fluid is controlled by a convective diffusion equation, which is divided into two cases, one in which the acid solution does not completely erode the rock (ε < 1) and the other in which the acid solution completely erodes the rock (ε=1).
The convective diffusion equation in the case where the acid solution does not completely erode the rock (ε < 1) takes into account the consumption of hydrogen ions at the rock surface and the change in porosity:
the convective diffusion equation with complete erosion of the rock by the acid solution (epsilon=1) does not take into account the consumption of hydrogen ions at the rock surface and the change in porosity:
In the method, in the process of the invention, Is Darcy speed vector, m/s; k is the stratum permeability, m 2; mu is the viscosity of the acid liquor and Pa.s; p is the acid liquor pressure, pa; epsilon is the formation porosity; t is the reaction time, s; c f is the acid concentration in the rock pores, mol/m 3; de is the acid liquor diffusion tensor, m 2/s;kc is the acid liquor local mass transfer coefficient, m/s; a v is the pore area of a unit volume of rock, m 2/m3; Cs is the acid liquor concentration on the surface of the rock, and mol/m 3; alpha is the rock mass which can be eroded by acid liquor in unit mole, kg/mol; ρ s is the rock density, kg/m 3.
(2) Acid flow in cracks
The flow of acid liquid in the natural cracks corresponds to different mechanisms from the flow in the matrix, the flow in the natural cracks is free flow, and the flow in the matrix is porous medium seepage controlled by Darcy's law. The flow of the acid liquid in the natural cracks is regarded as a region with larger permeability according to the concept of equivalent permeability, the erosion phenomenon of the acid liquid in the fractured stratum is researched by utilizing the mathematical model, and the natural cracks with larger influence on the pressure field are subjected to grid encryption, so that the calculation speed is increased, and the convergence of calculation is ensured.
(A-b) establishing a pore scale model for providing parameter support for the darcy scale model, wherein the parameters in the step (a-b) comprise permeability, pore radius, specific surface area, porosity, diffusion tensor and mass transfer coefficient.
(1) Relation between permeability, pore radius, specific surface area and porosity
The formation permeability, the pore radius and the specific surface area are directly related to the porosity, and the relation between the formation permeability, the pore radius, the specific surface area and the porosity is described by adopting an empirical formula:
Wherein epsilon (0 < epsilon < 1), k and r p、av are respectively porosity, permeability, pore radius and specific surface area; epsilon 0、k0、 r0、a0 is the initial porosity, permeability, pore radius, specific surface area, respectively; β is a constant related to the pore structure, taking β=1.
In general, the flowing speed of acid liquid in stratum is very small, so that the acid liquid can be regarded as laminar flow movement, cracks can be regarded as thinner circular pipes, and the flow is inspected by using a circular pipe laminar flow formula.
Wherein Q is flow, cm 3/s; ΔP is the driving differential pressure, 0.1MPa; d is crack diameter, cm; a is the cross-sectional area, cm 2; mu is the viscosity of the fluid, pa.s; l is the crack length, cm.
The flow calculated using the darcy formula is as follows.
When the seam width is 0.2cm, calculating based on the formula (6) and the formula (7) to obtain the equivalent permeability corresponding to the natural cracks as k=D 2/32＝125×103μm2; let natural fracture porosity epsilon max＝0.999(ε0＝0.05、k0 = 0.32), substituting formula (5) to obtain permeability K:
K is of the same order of magnitude as K, i.e. from the point of view of flow resistance it is reasonable to equate a natural fracture of width 0.2cm to a matrix of porosity 0.999. For natural cracks with a slit width exceeding 0.2cm, the natural crack is treated with a slit width equivalent to 0.2cm, since the permeability of the natural crack relative to the matrix is already quite high, and the slit width is not a factor limiting the flow conductivity of the crack (product of permeability and slit width).
(2) Diffusion tensor, mass transfer coefficient
The method for calculating the diffusion tensor comprises the following steps: related to the molecular diffusion coefficient Dm, pore structure, flow velocity, etc., wherein peclet number is a dimensionless number representing the ratio of convection to diffusion.
The diffusion tensor is divided into a horizontal diffusion tensor D eX and a vertical diffusion tensor D eT by the deposition compaction of the stratum to make the pore structure different in the transverse and longitudinal directions, and the formula is as follows:
DeX＝(αos+λx·PeP)Dm (10)
DeT＝(αos+λT·PeP)Dm (11)
Where α os is a constant related to pore structure, taking α os =0.5; λx=0.5, λ T =0.1 were obtained from core diffusion experiments; dm is the molecular diffusion coefficient; pe p is the Peclet number.
The mass transfer coefficient k c is calculated by the following steps:
wherein Sh ∞ is a progressive Shermood number; re p is the pore size Reynolds number, Sc is the Schmitt number,
And step two, gridding the three-dimensional ground stress field model of the reservoir with the well bore, and endowing parameters obtained by calculation of the double-scale mathematical model in the step one to grid units and nodes of the three-dimensional ground stress field model of the reservoir with the well bore after gridding treatment.
It should be noted that the above-described embodiments provide a more complete understanding of the present invention to those skilled in the art, but do not limit the present invention in any way. Therefore, although the present invention has been described in detail with reference to the drawings and examples, it will be understood by those skilled in the art that the present invention may be modified or equivalently replaced, and in any case, all technical solutions and changes thereof without departing from the spirit and scope of the present invention should be covered in the protection scope of the present patent.
Claims (7)
1. The well type optimization design method based on the fracture-cavity type oil reservoir three-dimensional ground stress field distribution is characterized by comprising the following steps of:
S1, collecting reservoir ground stress field distribution data, natural fracture occurrence data and karst cave distribution data of a fracture-cave type oil reservoir, and establishing a reservoir three-dimensional ground stress field model with karst cave and natural fracture in a simulation mode, wherein the reservoir ground stress field distribution data comprise azimuth data and size data of ground stress;
S2, setting a shaft azimuth according to azimuth data and size data of horizontal ground stress, selecting a plurality of shaft well bevels within a range of-90 degrees to 90 degrees, and respectively adding a shaft model into the same three-dimensional ground stress field model of the reservoir with the karst cave and the natural fracture to obtain a three-dimensional ground stress field model of the reservoir with the shaft;
S3, simulating liquid injection into a three-dimensional ground stress field model of the reservoir with the shaft by adopting the same liquid injection mode and liquid injection amount, and calculating a fracture-hole communication coefficient omega under each selected shaft oblique angle according to the number of communicated natural fractures and the number of communicated natural holes after simulated liquid injection;
S4, comparing the fracture-cavity communication coefficients under the selected wellbore well angles to obtain the optimized optimal wellbore well angles and the optimized wellbore azimuth angles.
2. The well type optimization design method based on the three-dimensional ground stress field distribution of the fracture-cavity oil reservoir according to claim 1, wherein in S3, a calculation formula of the fracture-cavity communication coefficient Ω is Ω=0.5×n+0.75×m, where n is the number of natural cracks communicated after simulated injection, and m is the number of natural holes communicated after simulated injection.
3. The method for optimizing the design of the well pattern based on the three-dimensional ground stress field distribution of the fracture-cavity oil reservoir according to claim 1 or 2, wherein in the step S2, a shaft azimuth is set according to azimuth data and magnitude data of horizontal ground stress, specifically, an azimuth of horizontal minimum ground stress is obtained according to the azimuth data and magnitude data of horizontal ground stress, and the set shaft azimuth is the azimuth of the horizontal minimum ground stress.
4. The method for optimizing the design of the well pattern based on the three-dimensional ground stress field distribution of the fracture-cavity oil reservoir according to claim 1 or 2, wherein in the step S4, when the fracture-cavity communication coefficient Ω value under each selected well-cavity well-tilt angle is the largest, the corresponding well-tilt angle is the optimized optimal well-cavity well-tilt angle.
5. The method for optimizing the design of the well pattern based on the three-dimensional ground stress field distribution of the fracture-cavity oil reservoir according to claim 3, wherein in the step S4, when the fracture-cavity communication coefficient omega value under each selected well-cavity well oblique angle is the maximum, the corresponding well oblique angle is the optimized optimal well-cavity well oblique angle.
6. The well type optimization design method based on the three-dimensional ground stress field distribution of the fracture-cavity oil reservoir according to claim 1, 2 or 5, wherein the natural fracture occurrence data comprise the number of natural fractures and the distribution situation data of the natural fractures in the ground stress field of the reservoir; the karst cave distribution data comprise the number of karst cave and distribution situation data of the karst cave in a reservoir ground stress field.
7. The method for well-type optimization design based on the three-dimensional ground stress field distribution of the fracture-cavity oil reservoir according to claim 3, wherein the reservoir ground stress field distribution data of the fracture-cavity oil reservoir at least comprises the magnitude and the direction of horizontal maximum ground stress, the magnitude and the direction of horizontal minimum ground stress and the magnitude and the direction of vertical stress.
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