CN111651848B - Stress-sensitive oil reservoir vertical well fluid production capacity prediction method and device - Google Patents
Stress-sensitive oil reservoir vertical well fluid production capacity prediction method and device Download PDFInfo
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Abstract
The invention provides a method and a device for predicting the liquid production capacity of a vertical well of a stress-sensitive oil reservoir, wherein the method comprises the following steps: obtaining static parameters of the reservoir and the fluid and related production parameters of the oil well to be researched; determining the liquid production amounts under different bottom hole flowing pressures according to the static parameters and the related production parameters based on a relational expression between the liquid production amounts of the stress-sensitive oil reservoir vertical well and the bottom hole flowing pressures; and predicting the liquid production capacity of the researched oil well according to the liquid production amounts under the different bottom hole flowing pressures. According to the scheme, the stress sensitivity of the reservoir and the change of the average pressure of the oil reservoir are considered, the actual situation of oil, gas and water three-phase co-production near the bottom of the well is also considered, the liquid production capacity of the vertical well of the fractured oil reservoir can be accurately predicted, and support is provided for efficient development of the oil reservoir.
Description
Technical Field
The invention relates to the technical field of oil well productivity prediction of oil development, in particular to a method and a device for predicting the liquid production capacity of a vertical well of a stress-sensitive oil reservoir.
Background
A large number of fractured reservoirs are discovered worldwide in succession. The lithology of the reservoir is complex, and the types of the reservoir are various, including low-permeability sandstone fractured reservoirs, conglomerate fractured reservoirs, carbonate fractured reservoirs, igneous rock fractured reservoirs and the like. The fractured reservoir is a dual-medium reservoir, and has strong stress sensitivity during pressure-reducing exploitation, so that the reservoir deforms, and the permeability and the productivity are greatly reduced; water channeling is easy to occur along cracks during bottom water or water injection development, stratum near a shaft can also be degassed, and the unfavorable situation of oil-gas-water three-phase flow occurs, namely the problems of reservoir stress sensitivity and multiphase flow exist in fractured reservoirs.
The existing research on the prediction of the liquid production capacity of the oil well mainly focuses on the derivation and establishment of a relation equation between the oil production amount of the oil well and the bottom hole flowing pressure under a single-phase or two-phase condition, and mainly comprises a pure oil phase productivity equation and an oil-gas two-phase productivity equation. The former is represented by a steady-state capacity equation (1) and a quasi-steady-state capacity equation (2), and the latter is represented by a Vogel capacity equation (3) and a Fetkovich capacity equation (4).
In formula (1): q-well surface production, m 3 /d；K o Effective permeability of the oil layer, μm 2 ；B o Crude oil volume factor, m 3 /m 3 ；μ o -formation oil viscosity, mpa.s; h-effective thickness of oil layer, m;
-reservoir mean pressure, MPa; p is a radical of wf -bottom hole flow pressure, MPa; r is e -drainage radius, m; r is a radical of hydrogen w -wellbore radius, m; s-epidermal coefficient, dimensionless.
In the formula (2): the definition and the unit of the physical quantity are the same as those of the formula (1).
In formula (3):Q omax maximum surface production of oil well of dissolved gas drive reservoir, m 3 D; the definitions and units of the remaining physical quantities are the same as those of formula (1).
In formula (4):
MPa -1 ；K ro oil phase relative permeability, μm 2 (ii) a The definitions and units of the remaining physical quantities are the same as those of formula (1).
The four productivity equations have two disadvantages: firstly, the bottom hole flow is assumed to be a pure oil phase or an oil-gas two-phase, the water phase flow possibly existing at the bottom hole is not considered, and the actual liquid production capacity of an oil well cannot be accurately reflected; and secondly, the stress sensitivity of the fractured reservoir is not considered. Meanwhile, the four equations have a certain application range: formula (1) is suitable for constant pressure boundary reservoirs, but the actual situation rarely meets such reservoirs; the formula (2) is suitable for the closed boundary oil reservoir; formulas (3) and (4) are suitable for dissolved gas drive reservoirs, i.e., saturated reservoirs, but not for unsaturated reservoirs.
Based on this, some experts propose to use a pseudo-pressure function to derive the low permeability reservoir capacity equation with stress sensitivity:
in formula (5): q-bottom well production, t/d; k is i Effective permeability of the oil layer, μm 2 ；μ i -formation oil viscosity, mpa.s; rho i Formation crude oil density, 10 3 kg/m 3 (ii) a h-effective thickness of oil layer, m; alpha-reservoir stress sensitivity index, MPa -1 ；p i -initial reservoir pressure, MPa; p is a radical of formula wf -bottom hole flow pressure, MPa; r is a radical of hydrogen e -drainage radius, m; r is w -wellbore radius, m; s-epidermal coefficient, dimensionless.
Equation (5) considers the stress sensitivity of the reservoir, but the precondition for this is that only pure oil phase flow is required in the reservoir, and the average reservoir pressure during production is assumed to be approximately constant, which is contrary to the actual production situation.
Some experts address the problem of oil-gas-water three-phase flow by first proposing inflow dynamics of vertical well three-phase flow through numerical simulation:
in formula (6): q-oil well ground fluid production, m 3 /d；q o Oil well surface oil production, m 3 /d；q w Oil well surface water production, m 3 /d；q omax Maximum oil production on the surface of the well, m 3 /d；q wmax Maximum water production on the surface of the well, m 3 /d；p r -average reservoir pressure, MPa; p is a radical of wf Bottom hole flow pressure, MPa.
Formula (6) provides a method for treating oil-gas-water three-phase flow, but does not consider the stress sensitivity of a reservoir and is only suitable for saturated oil reservoirs.
The Petrobras method and the three-phase flow IPR general yield analysis method appear in the follow-up of the solution of the oil-gas-water three-phase flow problem. And (3) the Petrobras takes the weighted average value of the pure oil phase productivity equation and the pure water phase productivity equation according to the water content, establishes an oil, gas and water three-phase inflow dynamic relation of the perfect well, and is suitable for both saturated oil reservoirs and unsaturated oil reservoirs. The Petrobras method is simple in principle and operation and widely applied. On the basis of the Petrobras method, some experts consider oil well damage and oil well production increasing measures in sequence, correct the Vogel equation by using two-phase flow efficiency, and respectively establish oil, gas and water three-phase inflow dynamic relations of an imperfect well and a super-perfect well. The three-phase flow IPR general productivity analysis method is only suitable for saturated oil reservoirs, and parameters such as flow efficiency and the like need to be calculated firstly in the specific use process, so that the method is relatively complicated and less in use. The three-phase inflow dynamic relationship provides a method for predicting the liquid production capacity of the oil well when oil, gas and water of a common oil reservoir are produced simultaneously. However, none of these methods take stress sensitivity into account and are not applicable to fractured reservoirs.
In general, the methods described above all have certain limitations, and are inaccurate in predicting the fluid production capacity of a vertical well in a fractured reservoir, which brings challenges to optimization of oil well extract and planning of oil field productivity. Accurate prediction of the liquid production capacity of a vertical well of a stress-sensitive oil reservoir is one of the key problems in efficient development of fractured oil reservoirs.
Disclosure of Invention
The embodiment of the invention provides a method and a device for predicting the liquid production capacity of a vertical well of a stress-sensitive oil reservoir, simultaneously considers the stress sensitivity, the oil reservoir pressure change and the three-phase inflow characteristics of oil, gas and water, establishes a liquid production equation, improves the prediction precision of the liquid production capacity of the vertical well of the fractured oil reservoir, and provides support for the efficient development of the fractured oil reservoir.
The embodiment of the invention provides a method for predicting the liquid production capacity of a vertical well of a stress-sensitive oil reservoir, which comprises the following steps:
obtaining static parameters of the reservoir and the fluid and related production parameters of the oil well to be researched;
determining the liquid production amounts under different bottom hole flowing pressures according to the static parameters and the related production parameters based on a relational expression between the liquid production amounts of the stress-sensitive oil reservoir vertical well and the bottom hole flowing pressures;
and predicting the liquid production capacity of the researched oil well according to the liquid production amounts under the different bottom hole flowing pressures.
The embodiment of the invention also provides a device for predicting the liquid production capacity of the stress-sensitive oil reservoir vertical well, which comprises:
the parameter acquisition module is used for acquiring static parameters of the reservoir and the fluid and related production parameters of the researched oil well;
the liquid production amount determining module is used for determining liquid production amounts under different bottom hole flowing pressures according to the static parameters and the related production parameters based on a relational expression between the liquid production amount of the stress-sensitive oil reservoir vertical well and the bottom hole flowing pressure;
and the liquid production capacity prediction module is used for predicting the liquid production capacity of the oil well under study according to the liquid production quantities under the different bottom hole flowing pressures.
The embodiment of the invention also provides computer equipment which comprises a memory, a processor and a computer program which is stored on the memory and can run on the processor, wherein the processor executes the computer program to realize the stress-sensitive reservoir vertical well fluid production capacity prediction method.
The embodiment of the invention also provides a computer readable storage medium, and the computer readable storage medium stores a computer program for executing the stress-sensitive reservoir vertical well fluid production capacity prediction method.
In the embodiment of the invention, static parameters of the reservoir and the fluid and related production parameters of the researched oil well are obtained, and the parameters take the actual situation of oil, gas and water co-production near the bottom of the well into consideration; and then determining the liquid production amounts under different bottom hole flowing pressures according to the static parameters and the related production parameters based on a relational expression of the liquid production amounts of the vertical wells of the stress-sensitive oil reservoirs and the bottom hole flowing pressures, wherein the stress sensitivity of the reservoirs and the change of the average pressure of the oil reservoirs are considered in the step, and finally, the liquid production capacity of the researched oil wells is predicted according to the liquid production amounts under the different bottom hole flowing pressures. The method improves the prediction precision of the vertical well fluid production capacity of the fractured reservoir and provides support for the efficient development of the fractured reservoir.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings used in the description of the embodiments or the prior art will be briefly described below, it is obvious that the drawings in the following description are only some embodiments of the present invention, and for those skilled in the art, other drawings can be obtained according to the drawings without creative efforts.
FIG. 1 is a flow chart of a method for predicting fluid production capacity of a vertical well of a stress-sensitive reservoir according to an embodiment of the present invention;
FIG. 2 is a flow chart of a method for predicting the fluid production capacity of a vertical well of a stress-sensitive reservoir according to an embodiment of the present invention;
FIG. 3 is a flow chart of a method for predicting the fluid production capacity of a vertical well of a stress-sensitive reservoir according to an embodiment of the present invention (III);
FIG. 4 is a flow chart of a method for predicting the fluid production capacity of a vertical well of a stress-sensitive reservoir according to an embodiment of the present Invention (IV);
FIG. 5 is a flow chart of a method for predicting fluid production capacity of a vertical well of a stress-sensitive reservoir according to an embodiment of the present invention (V);
FIG. 6 is a flow chart of a method for predicting the fluid production capacity of a vertical well of a stress-sensitive reservoir according to an embodiment of the present invention (VI);
FIG. 7 is a structural diagram of a stress-sensitive reservoir vertical well fluid production capability prediction device according to an embodiment of the present invention;
FIG. 8 is a structural block diagram of a stress-sensitive reservoir vertical well fluid production capacity prediction apparatus provided by an embodiment of the present invention (II);
FIG. 9 is a structural block diagram (III) of a stress-sensitive reservoir vertical well fluid production capability prediction device provided by an embodiment of the invention;
FIG. 10 is a structural block diagram of a stress-sensitive reservoir vertical well fluid production capability prediction device provided by an embodiment of the Invention (IV);
FIG. 11 is a comparison of predicted well fluid production versus bottom hole flow pressure under various conditions provided by embodiments of the present invention;
FIG. 12 is a comparison of a calculated fluid production index of a well versus bottom hole flow pressure under different conditions, according to an embodiment of the present invention.
Detailed Description
The technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the drawings in the embodiments of the present invention, and it is obvious that the described embodiments are only a part of the embodiments of the present invention, and not all of the embodiments. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present invention.
The fractured reservoir has two main characteristics, namely strong stress sensitivity of the reservoir and synchronous production of oil, gas and water of an oil well. The superposition of the two results in the prior art method not being capable of accurately predicting the vertical well fluid production capacity of the fractured reservoir. The invention provides a vertical well fluid production capacity prediction method which comprehensively considers stress sensitivity, reservoir pressure change and oil-gas-water three-phase flow and has a wide application range, improves the prediction precision of the vertical well fluid production capacity of the fractured reservoir and provides support for the efficient development of the fractured reservoir.
Fig. 1 is a flow chart (i) of a method for predicting fluid production capacity of a vertical well of a stress-sensitive reservoir according to an embodiment of the present invention, and as shown in fig. 1, the method includes:
step 101: obtaining static parameters of the reservoir and the fluid and related production parameters of the oil well to be researched;
step 102: determining the liquid production amounts under different bottom hole flowing pressures according to the static parameters and the related production parameters based on a relational expression between the liquid production amounts of the stress-sensitive oil reservoir vertical well and the bottom hole flowing pressures;
step 103: and predicting the liquid production capacity of the researched oil well according to the liquid production quantities under the different bottom hole flowing pressures.
In an embodiment of the present invention, the obtained static parameters of the reservoirs and fluids include: bubble point pressure p of oil reservoir b Volume coefficient B of crude oil, viscosity mu of stratum crude oil, thickness h of oil layer and initial permeability K of fracture system f0 Initial permeability K of the matrix system m0 Initial porosity phi of fracture system f0 Initial reservoir pressure p 0 Average reservoir pressure at production
Radius r of oil drainage e Stress sensitivity index alpha and reservoir equivalent permeability K (ii) a Relevant production parameters of the oil well studied included: radius of shaft r w Skin coefficient S, bottom hole flow pressure p wf And water content of oil well f w 。
Wherein, the parameters are obtained by the following method:
1) Through to the groundSampling the lower fluid and carrying out high-pressure physical property analysis experiment to obtain the bubble point pressure p of the oil reservoir b Volume factor B and formation crude oil viscosity mu;
2) Obtaining the radius r of the well bore through the well drilling data w ；
3) Obtaining the thickness h of an oil layer and the initial permeability K of a fracture system through conventional well logging explanation f0 Initial permeability K of the matrix system m0 And initial porosity of fracture system f0 ；
4) Obtaining the initial pressure p of the oil reservoir according to dynamic tests such as pressure recovery well testing or pressure drop well testing 0 Average reservoir pressure at production
Radius r of oil drainage e And an epidermal coefficient S;
5) Obtaining bottom hole flowing pressure p by conventional pressure test wf ；
6) Obtaining stress sensitivity index alpha of equivalent permeability of fractured reservoir through stress sensitivity experiment K ；
7) Obtaining the water content f of the oil well through the sampling analysis of the ground wellhead w 。
In the embodiment of the present invention, as shown in fig. 2, step 102 specifically includes:
step 1021: determining the initial equivalent permeability of the fractured reservoir according to the static parameters;
step 1023: and substituting the static parameters, the related production parameters and the initial equivalent permeability into a relational expression between the liquid production capacity of the stress sensitive oil reservoir vertical well and the bottom hole flowing pressure to determine the liquid production capacities under different bottom hole flowing pressures.
The calculation formula of the initial equivalent permeability of the fractured reservoir is as follows:
wherein,
denotes the initial equivalent permeability, μm, of the reservoir 2 ；K m0 Denotes the initial permeability, μm, of the matrix system 2 ；φ f0 Representing the initial porosity of the fracture system without dimension; k is f0 Denotes the initial permeability, μm, of the fracture system 2 。
In the embodiment of the invention, because the oil reservoir saturation types are divided into the unsaturated oil reservoir and the saturated oil reservoir, the vertical well liquid production prediction equation is respectively established for the unsaturated oil reservoir and the saturated oil reservoir, and the method is still feasible when the average pressure of the oil reservoir changes in the production process, so that the method has great significance for the fractured oil reservoir developed by pressure reduction and has wider application range. Therefore, as shown in fig. 3, step 102 further specifically includes:
step 1022: determining the oil reservoir saturation type according to the static parameters (namely according to the bubble point pressure of the oil reservoir and the initial pressure of the oil reservoir);
step 1023 (specifically): and substituting the static parameters, the related production parameters and the initial equivalent permeability into a relational expression between the liquid production capacity of the stress-sensitive oil reservoir vertical well corresponding to the corresponding oil reservoir saturation type and the bottom hole flowing pressure according to the oil reservoir saturation type, and determining the liquid production capacities under different bottom hole flowing pressures.
The determination standard of the oil reservoir saturation type is as follows:
when p is 0 ≥p b When the oil reservoir is saturated, the oil reservoir is unsaturated; when p is 0 ＜p b When the oil reservoir saturation type is a saturated oil reservoir;
wherein p is 0 Representing the initial pressure of the reservoir; p is a radical of b Representing reservoir bubble point pressure.
Aiming at different oil reservoir saturation types, the relational expressions of the liquid production capacity and the bottom hole flowing pressure of the stress sensitive oil reservoir vertical well are respectively as follows:
1) Unsaturated reservoirs (p) 0 ≥p b )：
2) Full of foodAnd oil reservoir (p) 0 ＜p b )
Wherein Q is 1 Represents the oil well ground fluid production quantity m 3 /d；
Denotes the initial equivalent permeability, μm, of the reservoir 2 (ii) a h represents the oil layer thickness, m; μ represents formation crude oil viscosity, mpa.s; b represents the volume coefficient of crude oil, m 3 /m 3 (ii) a S represents the epidermis coefficient and is dimensionless; r is e Represents the drainage radius, m; r is w Represents the wellbore radius, m; f. of w The water content of the oil well is expressed without dimension; alpha is alpha K Stress sensitivity index, MPa, representing the equivalent permeability of the reservoir -1 ；p 0 Represents the initial pressure of the reservoir, MPa;
represents the average reservoir pressure in MPa during production; p is a radical of wf Representing the bottom hole flow pressure, MPa p b The bubble point pressure of the reservoir, MPa.
In the invention, when the stress sensitivity index is 0, the stress sensitivity is correspondingly not considered; when the water content of the oil well is 0, the method corresponds to the situation of oil-gas two-phase flow.
In the embodiment of the present invention, after obtaining the fluid production rates at different bottom hole flowing pressures, the fluid production rates at different bottom hole flowing pressures can be directly used to predict the fluid production capacity of the oil well under study, i.e. step 103. However, since the liquid production rates under different bottom hole flowing pressures are a pile of values, the prediction situation cannot be observed well intuitively, and based on this, as shown in fig. 4, the method for predicting the liquid production capacity of the vertical well of the stress-sensitive reservoir of the invention may further include:
step 104: drawing a relation curve of the liquid production amount and the bottom hole flowing pressure according to the liquid production amounts under the different bottom hole flowing pressures;
step 103 specifically comprises:
and predicting the liquid production capacity of the oil well to be researched according to the relation curve of the liquid production amount and the bottom hole flowing pressure.
In the embodiment of the invention, the fluid production capacity is predicted by only using the fluid production amount under different bottom flow pressures, and the fluid production capacity can also be predicted by using the fluid production amount under different bottom flow pressures and the fluid production index of the oil well under different bottom flow pressures. Based on this, as shown in fig. 5, the method for predicting the fluid production capacity of the vertical well of the stress-sensitive reservoir of the invention may further include:
step 105: determining the liquid production index of the oil well under different bottom hole flowing pressures according to the liquid production amount under different bottom hole flowing pressures;
the calculation formula of the liquid production index of the oil well under different bottom hole flowing pressures is as follows:
wherein, J l Denotes the oil well fluid production index, m 3 /d/MPa；Q l Represents the oil well ground fluid production quantity m 3 /d；
The average reservoir pressure in MPa during production; p is a radical of wf Representing the bottom hole flow pressure, MPa.
Step 106 comprises:
and predicting the liquid production index of the researched oil well according to the liquid production indexes of the oil wells under different bottom hole flowing pressures.
Similarly, because the fluid production index of the oil well under different bottom hole flowing pressures is a pile of values, the prediction situation cannot be observed well intuitively, and based on the result, as shown in fig. 6, the method for predicting the fluid production capacity of the vertical well of the stress-sensitive oil reservoir can further comprise the following steps:
step 107: drawing a relation curve of the liquid production index and the bottom hole flowing pressure according to the oil well liquid production index under the different bottom hole flowing pressures;
step 106 specifically includes:
and predicting the fluid production index of the oil well to be researched according to the relationship curve of the fluid production index and the bottom hole flowing pressure.
Based on the same inventive concept, the embodiment of the invention also provides a device for predicting the fluid production capacity of the vertical well of the stress-sensitive oil reservoir, which is described in the following embodiment. Because the principle of solving the problems of the stress sensitivity reservoir vertical well fluid production capability prediction device is similar to that of the stress sensitivity reservoir vertical well fluid production capability prediction method, the stress sensitivity reservoir vertical well fluid production capability prediction device can be implemented by the stress sensitivity reservoir vertical well fluid production capability prediction method, and repeated parts are not described again. As used hereinafter, the term "unit" or "module" may be a combination of software and/or hardware that implements a predetermined function. Although the means described in the embodiments below are preferably implemented in software, an implementation in hardware, or a combination of software and hardware is also possible and contemplated.
Fig. 7 is a structural block diagram (one) of a stress-sensitive reservoir vertical well fluid production capability prediction device according to an embodiment of the present invention, as shown in fig. 7, including:
a parameter obtaining module 701, configured to obtain static parameters of the reservoir and the fluid to which the reservoir belongs and related production parameters of the oil well under study;
a liquid production amount determining module 702, configured to determine liquid production amounts under different bottom-hole flowing pressures according to the static parameters and the related production parameters based on a relational expression between the liquid production amount of the stress-sensitive oil reservoir vertical well and the bottom-hole flowing pressure;
and the liquid production capacity prediction module 703 is used for predicting the liquid production capacity of the oil well under study according to the liquid production quantities under the different bottom hole flowing pressures.
In an embodiment of the present invention, the static parameters of the reservoir and the fluid include: bubble point pressure p of oil reservoir b Crude oil volume coefficient B, stratum crude oil viscosity mu, oil layer thickness h and initial permeability K of fracture system f0 Initial permeability K of the matrix system m0 Initial porosity phi of fracture system f0 Initial reservoir pressure p 0 Average reservoir pressure at production
Radius r of oil drainage e Stress sensitivity index alpha and reservoir equivalent permeability K (ii) a Relevant production parameters of the oil well studied included: radius of shaft r w Skin factor S, bottom hole flow pressure p wf And water content of oil well f w 。
In this embodiment of the present invention, the liquid production amount determining module 702 is specifically configured to:
determining the initial equivalent permeability of the fractured reservoir according to the static parameters;
and substituting the static parameters, the related production parameters and the initial equivalent permeability into a relational expression between the liquid production capacity of the stress sensitive oil reservoir vertical well and the bottom hole flowing pressure to determine the liquid production capacities under different bottom hole flowing pressures.
In this embodiment of the present invention, the liquid production amount determining module 702 is specifically configured to:
determining an oil reservoir saturation type according to the static parameters;
and substituting the static parameters, the related production parameters and the initial equivalent permeability into a relational expression between the liquid production amount of the stress sensitivity oil reservoir vertical well and the bottom hole flowing pressure corresponding to the corresponding oil reservoir saturation type according to the oil reservoir saturation type.
In the embodiment of the present invention, as shown in fig. 8, the method further includes:
a relation graph drawing module 704, configured to draw a relation curve between the liquid production amount and the bottom hole flowing pressure according to the liquid production amounts under the different bottom hole flowing pressures;
the fluid production capacity prediction module 703 is specifically configured to:
and predicting the liquid production capacity of the oil well to be researched according to the relation curve of the liquid production amount and the bottom hole flowing pressure.
In the embodiment of the present invention, as shown in fig. 9, the method further includes:
the oil well liquid production index determining module 705 is used for determining the oil well liquid production index under different bottom hole flowing pressures according to the liquid production amounts under the different bottom hole flowing pressures;
the fluid production index prediction module 706 is specifically configured to:
and predicting the liquid production index of the oil well under study according to the liquid production indexes of the oil wells under different bottom hole flowing pressures.
In an embodiment of the present invention, as shown in fig. 10, the relation graph plotting module 704 is further configured to:
drawing a relation curve of the liquid production index and the bottom hole flowing pressure according to the oil well liquid production index under the different bottom hole flowing pressures;
the fluid production index prediction module 706 is specifically configured to:
and predicting the liquid production index of the oil well to be researched according to the relation curve of the liquid production index and the bottom hole flowing pressure.
In this embodiment of the present invention, the liquid production amount determining module 702 is specifically configured to: determining the initial equivalent permeability of the fractured reservoir according to the formula (7)
In this embodiment of the present invention, the liquid production amount determining module 702 is specifically configured to:
based on the static parameter (reservoir initial pressure p) as follows 0 And reservoir bubble point pressure p b ) Determining the oil reservoir saturation type: when p is 0 ≥p b When the oil reservoir is saturated, the oil reservoir is unsaturated; when p is 0 ＜p b When the oil reservoir saturation type is a saturated oil reservoir;
in the embodiment of the invention, the relation between the liquid production capacity of the vertical well of the stress-sensitive oil reservoir corresponding to the unsaturated oil reservoir and the bottom hole flowing pressure is shown as a formula (8). The relation between the liquid production capacity of the stress-sensitive oil reservoir vertical well corresponding to the saturated oil reservoir and the bottom hole flowing pressure is shown as a formula (9).
In an embodiment of the present invention, the oil well fluid production index determining module 705 is specifically configured to: determining the fluid production index J of the well at different bottom hole flow pressures according to the formula (10) l 。
The embodiment of the invention also provides computer equipment which comprises a memory, a processor and a computer program which is stored on the memory and can be operated on the processor, wherein when the processor executes the computer program, the stress-sensitive reservoir vertical well fluid production capacity prediction method is realized.
The embodiment of the invention also provides a computer readable storage medium, and the computer readable storage medium stores a computer program for executing the method for predicting the fluid production capacity of the vertical well of the stress-sensitive oil reservoir.
The embodiment is as follows:
a block A of a foreign oil field is a newly-developed block and belongs to a typical fractured reservoir. At present, in the trial production stage, the potential of extraction liquid and the stable yield scale of the vertical well in the block are urgently needed to be determined so as to make the whole development plan of the block A. The P1 well is a vertical well in the trial production of the block. The P1 well is taken as a research oil well of a specific embodiment, and the oil well liquid production capacity of the block is predicted by applying the stress-sensitive oil reservoir vertical well liquid production capacity prediction method provided by the invention, so that technical support is provided for the development and construction of the A block.
The first step is as follows: static parameters of the reservoir and the fluid and related production parameters of the oil well to be researched are obtained, and the specific obtained parameter results are shown in table 1.
TABLE 1 basic parameter results table for study block and P1 well
The second step is that: according to the initial equivalent permeability calculation formula (7), the initial permeability K of the fracture system obtained in the first step is utilized f0 Initial permeability K of the matrix System m0 And initial porosity of fracture system f0 Determining the initial equivalent permeability of a fractured reservoir
Is 0.001191 μm 2 。
The third step: according to the initial reservoir pressure p in the first step 0 And reservoir bubble point pressure p b Has p of 0 ＞p b Determining the reservoir asAn unsaturated reservoir.
The fourth step: and determining that the A block is an unsaturated oil reservoir according to the third step, and selecting a formula (8) to calculate the liquid production of the P1 well. And substituting all the parameters obtained in the first step and the second step into a formula (8) to calculate the liquid production amount of the P1 well under different bottom hole flowing pressures, and substituting the liquid production amounts under different bottom hole flowing pressures into a liquid production index calculation formula (10) to calculate the liquid production index of the oil well, wherein the results are shown in a table 2.
TABLE 2 P1 related parameter calculation results table
The fifth step: and (3) drawing a relation curve of the liquid production amount of the P1 well and the bottom hole flowing pressure, namely a liquid production capacity prediction graph, as shown by a chain line in the figure 11. In order to compare the implementation effect of the invention, the relation curve of the oil well liquid production volume and the bottom hole flowing pressure under other three conditions is calculated and drawn, and the relation curve comprises the following steps: 1) Without considering the stress sensitivity and the oil-gas-water three-phase flow (taking the stress sensitivity index alpha) K =0 and oil well water content f w = 0), corresponding to the solid line in fig. 11; 2) Considering oil-gas-water three-phase flow without considering stress sensitivity (taking stress sensitivity index alpha) K =0 and oil well water content f w = 0.23), corresponding to the long dashed line in fig. 11; 3) Taking stress sensitivity into account but not oil-gas-water three-phase flow (taking stress sensitivity index alpha) K =0.05 and water content of oil well f w = 0.23), corresponding to the short dashed line in fig. 11. The black circle in FIG. 11 is the P1 well plot of fluid production versus bottom hole flow pressure for actual production. It is clear that the actual P1 well fluid production versus bottom hole flow pressure curve substantially matches the curve obtained using the present invention, but is very different from the curves calculated by the present invention under the other two conditions. Therefore, the technical scheme of the invention can improve the stress sensitivity of the oil reservoirAccuracy of well fluid production capability prediction.
Further, the fluid production index versus bottom hole flow pressure for the P1 well can be plotted as shown by the dashed and dotted line in FIG. 12. Similarly, the fluid production index versus bottom hole flow pressure for the other three conditions is calculated and plotted in FIG. 12, as compared to the actual fluid production index versus bottom hole flow pressure. The method comprises the following steps: 1) Without considering the stress sensitivity and the oil-gas-water three-phase flow (taking the stress sensitivity index alpha) K =0 and oil well water content f w = 0), corresponding to the solid line in fig. 12; 2) Considering oil-gas-water three-phase flow without considering stress sensitivity (taking stress sensitivity index alpha) K =0 and oil well water content f w = 0.23), corresponding to the long dashed line in fig. 12; 3) Taking stress sensitivity into account but not oil-gas-water three-phase flow (taking stress sensitivity index alpha) K =0.05 and oil well water content f w = 0.23), corresponding to the short dashed line in fig. 12. In fig. 12, the actual relationship curve of the P1 well fluid production index and the bottom hole flowing pressure is basically consistent with the relationship curve obtained by using the method, and the technical scheme of the invention can improve the accuracy of the prediction of the fluid production capacity of the stress sensitive oil reservoir in the vertical well.
And a sixth step: and predicting the liquid production capacity and the liquid production index of the oil well to be researched according to the relation curve of the liquid production capacity and the liquid production index of the drawn stress-sensitive oil reservoir vertical well and the bottom flowing pressure.
From the plotted curve of fluid production capacity and fluid production index versus bottom hole flow pressure for the P1 well, the fluid production capacity and fluid production index for the well at any bottom hole flow pressure can be predicted, for example: when the bottom hole flowing pressure is 47MPa, the corresponding liquid production amount is about 61m 3 D, liquid production index of about 3.3m 3 d/MPa; when the bottom hole flowing pressure is 33MPa, the corresponding liquid production amount is about 75m 3 D, liquid production index of about 2.3m 3 d/MPa. Meanwhile, the maximum liquid production of the P1 well is 77m 3 And d, the bottom hole flowing pressure is 25MPa, and the data can be used for determining the liquid extracting potential of the vertical well in the A block and providing technical support for the whole development and construction of the A block.
In conclusion, the stress sensitivity of the reservoir stratum and the actual situation of the oil, gas and water three-phase co-production near the bottom of the well are considered, the liquid production capacity of the vertical well of the fractured reservoir can be predicted more accurately, and support is provided for efficient development of the reservoir. Meanwhile, the method establishes a straight-well liquid production prediction equation aiming at the unsaturated oil reservoir and the saturated oil reservoir respectively, and is still feasible when the average pressure of the oil reservoir changes in the production process, so that the method has great significance for the fractured oil reservoir developed by pressure reduction. In addition, in the present invention, when the stress sensitivity index is 0, the case where the stress sensitivity is not considered is corresponded; when the water content of the oil well is 0, the method corresponds to the situation of oil-gas two-phase flow. Therefore, the method provided by the invention is more systematic and has wider application range.
As will be appreciated by one skilled in the art, embodiments of the present invention may be provided as a method, system, or computer program product. Accordingly, the present invention may take the form of an entirely hardware embodiment, an entirely software embodiment or an embodiment combining software and hardware aspects. Furthermore, the present invention may take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, and the like) having computer-usable program code embodied therein.
The present invention is described with reference to flowchart illustrations and/or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of the invention. It will be understood that each flow and/or block of the flow diagrams and/or block diagrams, and combinations of flows and/or blocks in the flow diagrams and/or block diagrams, can be implemented by computer program instructions. These computer program instructions may be provided to a processor of a general purpose computer, special purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, create means for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be stored in a computer-readable memory that can direct a computer or other programmable data processing apparatus to function in a particular manner, such that the instructions stored in the computer-readable memory produce an article of manufacture including instruction means which implement the function specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer implemented process such that the instructions which execute on the computer or other programmable apparatus provide steps for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
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 to the embodiment of the present invention by those skilled in the art. Any modification, equivalent replacement, or improvement made within the spirit and principle of the present invention should be included in the protection scope of the present invention.
Claims (18)
1. A method for predicting the liquid production capacity of a vertical well of a stress-sensitive oil reservoir is characterized by comprising the following steps:
obtaining static parameters of the reservoir and the fluid and related production parameters of the oil well to be researched;
determining the liquid production amounts under different bottom hole flowing pressures according to the static parameters and the related production parameters based on a relational expression between the liquid production amounts of the stress-sensitive oil reservoir vertical well and the bottom hole flowing pressures;
predicting the liquid production capacity of the oil well under study according to the liquid production quantities under the different bottom hole flowing pressures;
the method comprises the following steps of determining the liquid production amounts under different bottom hole flowing pressures according to the static parameters and the related production parameters based on a relational expression between the liquid production amounts and the bottom hole flowing pressures of the vertical wells of the stress-sensitive oil reservoirs, wherein the method comprises the following steps:
determining the initial equivalent permeability of the fractured reservoir according to the static parameters;
substituting the static parameters, the related production parameters and the initial equivalent permeability into a relational expression between the liquid production capacity of the stress sensitive oil reservoir vertical well and the bottom hole flowing pressure to determine the liquid production capacities under different bottom hole flowing pressures;
the method comprises the following steps of determining the liquid production amounts under different bottom hole flowing pressures according to the static parameters and the related production parameters based on a relational expression between the liquid production amounts and the bottom hole flowing pressures of the vertical wells of the stress-sensitive oil reservoirs, wherein the method comprises the following steps:
determining an oil reservoir saturation type according to the static parameters;
substituting the static parameter, the related production parameter and the initial equivalent permeability into a relational expression between the liquid production amount of the stress-sensitive oil reservoir vertical well and the bottom hole flowing pressure corresponding to the corresponding oil reservoir saturation type according to the oil reservoir saturation type;
and determining the initial equivalent permeability of the fractured reservoir according to the static parameters according to the following formula:
wherein,
denotes the initial equivalent permeability, μm, of the reservoir 2 ；K m0 Denotes the initial permeability of the matrix system, μm 2 ；φ f0 Representing the initial porosity of the fracture system without dimension; k is f0 Denotes the initial permeability of the fracture system, μm 2 ；
Determining the oil reservoir saturation type according to the static parameters, wherein the determining comprises the following steps:
when p is 0 ≥p b When the oil reservoir saturation type is an unsaturated oil reservoir; when p is 0 ＜p b When the oil reservoir saturation type is a saturated oil reservoir;
wherein p is 0 Representing the initial pressure of the reservoir; p is a radical of b Representing reservoir bubble point pressure.
2. The method for predicting the fluid production capacity of the stress-sensitive reservoir vertical well according to claim 1, wherein the static parameters of the reservoir and the fluid comprise: bubble point pressure p of oil reservoir b Volume coefficient B of crude oil, viscosity mu of stratum crude oil, thickness h of oil layer and initial permeability K of fracture system f0 Initial permeability K of the matrix system m0 Initial porosity phi of fracture system f0 Initial reservoir pressure p 0 Average reservoir pressure at production
Radius r of oil drainage e Stress sensitivity index alpha and reservoir equivalent permeability K (ii) a Relevant production parameters of the oil well studied included: radius of shaft r w Skin factor S, bottom hole flow pressure p wf And water content of oil well f w 。
3. The method for predicting fluid production capacity of a stress sensitive reservoir vertical well according to claim 1, further comprising:
drawing a relation curve of the liquid production amount and the bottom hole flowing pressure according to the liquid production amounts under the different bottom hole flowing pressures;
predicting the fluid production capacity of the oil well under study according to the fluid production quantities under the different bottom hole flowing pressures, and the method comprises the following steps:
and predicting the liquid production capacity of the oil well to be researched according to the relation curve of the liquid production amount and the bottom hole flowing pressure.
4. The method for predicting fluid production capacity of a stress sensitive reservoir vertical well according to claim 3, further comprising:
determining the liquid production index of the oil well under different bottom hole flowing pressures according to the liquid production amount under different bottom hole flowing pressures;
and predicting the liquid production index of the oil well under study according to the liquid production indexes of the oil wells under different bottom hole flowing pressures.
5. The method for predicting fluid production capacity of a stress sensitive reservoir vertical well according to claim 4, further comprising:
drawing a relation curve of the liquid production index and the bottom hole flowing pressure according to the oil well liquid production indexes under different bottom hole flowing pressures;
and predicting the liquid production index of the researched oil well according to the liquid production indexes of the oil wells under different bottom hole flowing pressures, wherein the method comprises the following steps:
and predicting the liquid production index of the oil well to be researched according to the relation curve of the liquid production index and the bottom hole flowing pressure.
6. The method for predicting the fluid production capacity of the stress-sensitive reservoir vertical well according to claim 1, wherein the relational expression between the fluid production capacity of the stress-sensitive reservoir vertical well corresponding to the unsaturated reservoir and the bottom hole flowing pressure is as follows:
wherein Q is 1 Represents the oil well ground fluid production quantity m 3 /d；
Denotes the initial equivalent permeability, μm, of the reservoir 2 (ii) a h represents the oil layer thickness, m; μ represents formation crude oil viscosity, mpa.s; b represents the volume coefficient of crude oil, m 3 /m 3 (ii) a S represents the epidermis coefficient and is dimensionless; r is a radical of hydrogen e Represents the drainage radius, m; r is a radical of hydrogen w Represents the wellbore radius, m; f. of w The water content of the oil well is expressed without dimension; alpha is alpha K Stress sensitivity index, MPa, representing the equivalent permeability of the reservoir -1 ；p 0 Represents the initial pressure of the reservoir, MPa;
represents the average reservoir pressure in MPa during production; p is a radical of wf Representing the bottom hole flow pressure, MPa p b The bubble point pressure of the reservoir, MPa.
7. The method for predicting the fluid production capacity of the stress-sensitive reservoir vertical well according to claim 1, wherein the relationship between the fluid production capacity of the stress-sensitive reservoir vertical well corresponding to the saturated reservoir and the bottom hole flowing pressure is as follows:
wherein Q 1 Represents the oil well ground fluid production quantity m 3 /d；
Denotes the initial equivalent permeability, μm, of the reservoir 2 (ii) a h represents the oil layer thickness, m; μ represents formation crude oil viscosity, mpa.s; b represents the volume coefficient of crude oil, m 3 /m 3 (ii) a S represents the epidermis coefficient and is dimensionless; r is e Represents the drainage radius, m; r is w Represents the wellbore radius, m; f. of w The water content of the oil well is expressed without dimension; alpha is alpha K Stress sensitivity index, MPa, representing the equivalent permeability of the reservoir -1 ；p 0 Represents the initial pressure of the reservoir, MPa;
the average reservoir pressure in MPa during production; p is a radical of wf Represents the bottom hole flow pressure, MPa; p is a radical of b The bubble point pressure of the reservoir, MPa.
8. The method of predicting the fluid production capacity of a stress sensitive reservoir vertical well according to claim 4, wherein the fluid production index of the well at different bottom hole flow pressures is determined from the fluid production at said different bottom hole flow pressures according to the following formula:
wherein, J l Denotes the oil well fluid production index, m 3 /d/MPa；Q l Represents the ground fluid production of the oil well, m 3 /d；
Represents the average reservoir pressure in MPa during production; p is a radical of wf Representing the bottom hole flow pressure, MPa.
9. A stress-sensitive reservoir vertical well fluid production capacity prediction device is characterized by comprising:
the parameter acquisition module is used for acquiring static parameters of the reservoir and the fluid and related production parameters of the researched oil well;
the liquid production amount determining module is used for determining liquid production amounts under different bottom hole flowing pressures according to the static parameters and the related production parameters based on a relational expression between the liquid production amount of the stress-sensitive oil reservoir vertical well and the bottom hole flowing pressure;
the liquid production capacity prediction module is used for predicting the liquid production capacity of the oil well under study according to the liquid production quantities under the different bottom hole flowing pressures;
wherein the liquid production amount determining module is specifically configured to:
determining the initial equivalent permeability of the fractured reservoir according to the static parameters;
substituting the static parameters, the related production parameters and the initial equivalent permeability into a relational expression between the liquid production capacity of the stress sensitive oil reservoir vertical well and the bottom hole flowing pressure to determine the liquid production capacities under different bottom hole flowing pressures;
wherein the liquid production amount determining module is specifically configured to:
determining an oil reservoir saturation type according to the static parameters;
substituting the static parameters, the related production parameters and the initial equivalent permeability into a relational expression between the liquid production capacity of the stress-sensitive oil reservoir vertical well and the bottom flowing pressure corresponding to the corresponding oil reservoir saturation type according to the oil reservoir saturation type;
wherein the liquid production amount determining module is specifically configured to:
and determining the initial equivalent permeability of the fractured reservoir according to the static parameters according to the following formula:
wherein,
denotes the initial equivalent permeability, μm, of the reservoir 2 ；K m0 Denotes the initial permeability, μm, of the matrix system 2 ；φ f0 Representing the initial porosity of the fracture system without dimension; k is f0 Denotes the initial permeability, μm, of the fracture system 2 ，
Wherein the liquid production amount determining module is specifically configured to:
determining the reservoir saturation type according to the static parameters in the following way:
when p is 0 ≥p b When the oil reservoir is saturated, the oil reservoir is unsaturated; when p is 0 ＜p b When the oil reservoir saturation type is a saturated oil reservoir;
wherein p is 0 Representing the initial pressure of the reservoir; p is a radical of formula b Indicating the reservoir bubble point pressure.
10. The stress-sensitive reservoir vertical well fluid production capability prediction device of claim 9, wherein the static parameters of the reservoir and fluid comprise: bubble point pressure p of oil reservoir b Volume coefficient B of crude oil, viscosity mu of stratum crude oil, thickness h of oil layer and initial permeability K of fracture system f0 Initial permeability K of the matrix system m0 Initial porosity phi of fracture system f0 Initial reservoir pressure p 0 Average reservoir pressure at production
Radius r of oil drainage e Stress sensitivity index alpha and reservoir equivalent permeability K (ii) a Relevant production parameters of the oil well studied included: radius of shaft r w Surface coefficient S, bottom hole flowing pressureForce p wf And water content of oil well f w 。
11. The stress-sensitive reservoir vertical well fluid production capability prediction device of claim 9, further comprising:
the relation curve drawing module is used for drawing a relation curve between the liquid production amount and the bottom hole flowing pressure according to the liquid production amounts under different bottom hole flowing pressures;
the fluid production capacity prediction module is specifically configured to:
and predicting the liquid production capacity of the oil well to be researched according to the relation curve of the liquid production amount and the bottom hole flowing pressure.
12. The stress-sensitive reservoir vertical well fluid production capacity prediction device of claim 11, further comprising:
the oil well liquid production index determining module is used for determining the oil well liquid production indexes under different bottom hole flowing pressures according to the liquid production amounts under the different bottom hole flowing pressures;
and the liquid production index prediction module is used for predicting the liquid production index of the oil well under study according to the liquid production indexes of the oil wells under different bottom hole flowing pressures.
13. The stress-sensitive reservoir vertical well fluid production capacity prediction device of claim 12, wherein the relational graph plotting module is further configured to:
drawing a relation curve of the liquid production index and the bottom hole flowing pressure according to the oil well liquid production index under the different bottom hole flowing pressures;
the fluid production index prediction module is specifically configured to:
and predicting the liquid production index of the oil well to be researched according to the relation curve of the liquid production index and the bottom hole flowing pressure.
14. The stress-sensitive reservoir vertical well fluid production capacity prediction device of claim 9, wherein the relationship between the fluid production capacity of the stress-sensitive reservoir vertical well corresponding to the unsaturated reservoir and the bottom hole flowing pressure is as follows:
wherein Q is 1 Represents the oil well ground fluid production quantity m 3 /d；
Denotes the initial equivalent permeability, μm, of the reservoir 2 (ii) a h represents the oil layer thickness, m; μ represents formation crude oil viscosity, mpa.s; b represents the volume coefficient of crude oil, m 3 /m 3 (ii) a S represents the epidermis coefficient and is dimensionless; r is e Represents the drainage radius, m; r is a radical of hydrogen w Represents the wellbore radius, m; f. of w The water content of the oil well is expressed without dimension; alpha is alpha K Stress sensitivity index, MPa, representing the equivalent permeability of the reservoir -1 ；p 0 Represents the initial pressure of the reservoir, MPa;
represents the average reservoir pressure in MPa during production; p is a radical of wf Representing the bottom hole flow pressure, MPa p b The bubble point pressure of the reservoir, MPa.
15. The stress-sensitive reservoir vertical well fluid production capacity prediction device of claim 9, wherein the relationship between the fluid production capacity of the stress-sensitive reservoir vertical well corresponding to the saturated reservoir and the bottom hole flowing pressure is as follows:
wherein Q is 1 Represents the oil well ground fluid production quantity m 3 /d；
Denotes the initial equivalent permeability, μm, of the reservoir 2 (ii) a h represents the oil layer thickness, m; mu means crude oil of stratumViscosity, mpa.s; b represents the volume coefficient of crude oil, m 3 /m 3 (ii) a S represents the epidermis coefficient and is dimensionless; r is e Represents the drainage radius, m; r is w Represents the wellbore radius, m; f. of w The water content of the oil well is expressed without dimension; alpha (alpha) ("alpha") K Stress sensitivity index, MPa, representing the equivalent permeability of the reservoir -1 ；p 0 Represents the initial pressure of the reservoir, MPa;
represents the average reservoir pressure in MPa during production; p is a radical of wf Represents the bottom hole flow pressure, MPa; p is a radical of b The bubble point pressure of the reservoir, MPa.
16. The stress-sensitive reservoir vertical well fluid production capability prediction device of claim 12, wherein the well fluid production index determination module is specifically configured to:
and determining the liquid production index of the oil well under different bottom hole flowing pressures according to the liquid production under different bottom hole flowing pressures according to the following formula:
wherein, J l Denotes the oil well fluid production index, m 3 /d/MPa；Q l Represents the oil well ground fluid production quantity m 3 /d；
The average reservoir pressure in MPa during production; p is a radical of wf Representing the bottom hole flow pressure, MPa.
17. A computer apparatus comprising a memory, a processor and a computer program stored on the memory and executable on the processor, wherein the processor when executing the computer program implements the method for predicting fluid production capability of a stress sensitive reservoir vertical well according to any of claims 1 to 8.
18. A computer readable storage medium storing a computer program for performing the method for predicting fluid production capability of a vertical well of a stress sensitive reservoir according to any one of claims 1 to 8.
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