CN106980758B - Rapid calculation method for flow field velocity of injection-production well pattern - Google Patents
Rapid calculation method for flow field velocity of injection-production well pattern Download PDFInfo
- Publication number
- CN106980758B CN106980758B CN201710159951.7A CN201710159951A CN106980758B CN 106980758 B CN106980758 B CN 106980758B CN 201710159951 A CN201710159951 A CN 201710159951A CN 106980758 B CN106980758 B CN 106980758B
- Authority
- CN
- China
- Prior art keywords
- injection
- production
- well
- flow
- calculation method
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Active
Links
Images
Classifications
-
- G—PHYSICS
- G16—INFORMATION AND COMMUNICATION TECHNOLOGY [ICT] SPECIALLY ADAPTED FOR SPECIFIC APPLICATION FIELDS
- G16Z—INFORMATION AND COMMUNICATION TECHNOLOGY [ICT] SPECIALLY ADAPTED FOR SPECIFIC APPLICATION FIELDS, NOT OTHERWISE PROVIDED FOR
- G16Z99/00—Subject matter not provided for in other main groups of this subclass
Abstract
The invention provides a method for quickly calculating the flow field speed of an injection-production well pattern, which comprises an injection-production flow line approximate calculation method, a flow line fault-winding calculation method, a correction factor C calculation method of flow line curvature to speed, a correction factor M calculation method of injection-production included angle to speed and a calculation method of the flow field speed of the injection-production well pattern. And establishing flow field distribution among injection and production wells according to the injection and production flow line approximate calculation method and the flow line fault-winding calculation method, calculating a correction factor of the flow field speed by using a correction factor C calculation method of the flow line curvature to the speed and a correction factor M calculation method of the injection and production included angle to the speed, and calculating the flow field speed by using the calculation method of the flow field speed of the injection and production well pattern. The invention solves the problems that the seepage mechanics method can not reflect the heterogeneous characteristics of the oil reservoir in the flow field research process and the numerical simulation method has the defects of complex process, long research period and limitation on requirements of personnel, so that the rapid calculation of the fluid velocity field of the injection-production well pattern is realized.
Description
Technical Field
The invention relates to the field of reservoir flow field distribution and flow field speed research in reservoir development and adjustment, in particular to the field of a method for quickly calculating the flow field speed of an injection-production well pattern.
Background
In the development process of an oil field, particularly in an ultrahigh water cut period, no matter a conventional hydrodynamics method is used for improving the recovery ratio, or a tertiary oil recovery mode of injecting a chemical agent is adopted, the primary tasks are to clear the injection and production flow field and the flow rate of an oil reservoir, determine the development contradiction of the water channeling direction, and perform targeted well pattern adjustment scheme design and liquid amount optimization design according to the flow field contradiction. Therefore, on the basis of the injection-production well pattern, a method for quickly calculating the flow field speed of the injection-production well pattern is established, and the method has very practical engineering theory and application value for enriching hydrodynamic methods, perfecting scheme design theory and improving scheme design efficiency and effect.
The research method of the injection-production well pattern flow field mainly comprises an interwell tracer, a well testing method, an oil reservoir engineering method, an interwell connectivity evaluation method based on an optimization principle, a numerical simulation method and a streamline simulation method, wherein the interwell tracer and the well testing method have high construction cost and long research period; the oil reservoir engineering method has high requirements on the business quality of researchers, and the analysis result is only limited to qualitative analysis; the optimization method is a fuzzy judgment method completely based on mathematical theory, and has strong result ambiguity and low availability; the numerical simulation and streamline tracking simulation method is influenced by the calculation precision of a pressure field, the principle of the method is scientific, but the result error is large, and the actual operability is poor. Therefore, aiming at the limitations of various methods, a set of rapid, simple and quantitative injection-production well pattern fluid velocity field calculation method capable of covering geology, well pattern well spacing and injection-production dynamics is required to be established, and the method has very important significance for reservoir engineering research.
Aiming at the characteristics of high cost and long periodicity of a tracer well testing method, strong qualitative quantification and weak quantification of an oil reservoir engineering method, strong fuzziness and low reliability of an optimization method, large periodicity and long error of a numerical simulation streamline tracking method and the like, a rapid calculation method of an injection and production well pattern fluid velocity field considering reservoir physical properties, well pattern well spacing and injection and production dynamics is established by utilizing a superposition principle on the basis of a seepage mechanics theory and considering the influence of reservoir heterogeneity to flow field velocity and the influence of streamline macroscopic curvature change and included angle between injection and production wells to flow velocity.
Disclosure of Invention
The embodiment of the invention mainly aims to provide a method for quickly calculating the flow field velocity of an injection-production well pattern, so as to overcome the defects that the existing flow field velocity calculation method is complex in method, high in cost and long in period, or is weak in qualitative strengthening and quantification and strong in ambiguity and low in reliability.
In order to achieve the above object, an embodiment of the present invention provides a method for quickly calculating a flow field velocity of an injection-production well pattern, including:
the method comprises the following steps of approximate calculation of injection and production flow lines based on a diamond model and a linear model, calculation of flow line winding faults based on the linear model, calculation of a correction factor C of flow line curvature to speed based on an arc length model, a linear model and a diamond model diameter expansion angle, calculation of a correction factor M of injection and production included angles to speed and calculation of a flow field speed of an injection and production well pattern.
Establishing flow field distribution among injection and production wells according to the injection and production flow line approximate calculation method based on the diamond model and the linear model and the flow line surrounding fault calculation method based on the linear model;
respectively applying a method for calculating a correction factor C of streamline curvature to speed and a method for calculating a correction factor M of injection-production included angle to speed based on the diameter expansion angles of the arc length model, the linear model and the diamond model to obtain a flow field speed correction factor C and a correction factor M;
and calculating the flow field velocity by using the method for calculating the flow field velocity of the injection-production well pattern.
By means of the technical scheme, the injection and production well network flow field velocity fast calculation method is established by taking reservoir physical properties, well pattern well spacing and injection and production dynamics into consideration through the superposition principle from the angle of oil reservoir dynamic and static combination, and taking the influences of the heterogeneity among wells, the macroscopic curvature change of the well tracks and the injection and production included angle on the flow field velocity into consideration. Compared with the prior art, the method has the advantages that the contradiction that a numerical simulation method is complex and long in period, a tracer well testing technology is high in cost and long in period, an oil reservoir engineering method is strong in qualitative degree and weak in quantitative property, and an optimization method is strong in fuzziness is solved, so that the calculation of the flow field speed of the injection-production well network is simple, rapid and quantitative, the hydrodynamic research method is further enriched, the scheme design theory is perfected, the scheme design efficiency and effect are improved, and the method has a very practical engineering theory application value.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings required to be used in the description of the embodiments will be briefly introduced below, and it is obvious that the drawings in the following description are only some embodiments of the present invention, and it is obvious for those skilled in the art that other drawings can be obtained according to the drawings without inventive labor.
Fig. 1 is a schematic flow chart of rapid calculation of a flow field velocity of an injection-production well pattern according to an embodiment of the present invention;
FIG. 2 is a schematic diagram illustrating a calculation principle of a diamond model trajectory according to an embodiment of the present invention;
FIG. 3 is a schematic diagram illustrating a principle of calculating a trajectory of a linear model according to an embodiment of the present invention;
FIG. 4 is a schematic view of an over-fault streamline provided by an embodiment of the present invention;
FIG. 5 is a schematic diagram of a principle of macroscopic curvature correction provided by an embodiment of the present invention;
FIG. 6 is an exploded view of a circular arc flow tube model according to an embodiment of the present invention;
FIG. 7 is a calculation of the diameter expansion angle of the circular arc length model according to an embodiment of the present invention;
FIG. 8 is a calculation of a diameter expansion angle of the linear model according to the first embodiment of the present invention;
FIG. 9 is a calculation of a diamond model expanding angle according to an embodiment of the present invention;
FIG. 10 is a schematic view illustrating the calculation of the injection-production included angle according to an embodiment of the present invention;
FIG. 11 is a schematic diagram of a transverse heterogeneous linear model provided in accordance with an embodiment of the present invention;
fig. 12 is a flow field velocity diagram of the heterogeneity ④: ③: 400: ④: ③: 550: 250: ④: ③: 700:100 according to the first 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.
Example one
The embodiment provides a method for rapidly calculating a flow field velocity of an injection-production well pattern, as shown in fig. 1, the method includes:
step 1: injection-production streamline approximate calculation method based on diamond model and linear model
Let the P coordinate of any point between injection wells and production wells be (X)p，Yp) Respectively calculating any point P to the water injection well Inj (X)1，Y1) Distance d of1And to the production well Pro (X)2，Y2) Distance d of2。
(1) Injection-production streamline approximate calculation method based on diamond model
For the straight line model, a straight line segment d is shown in FIG. 21Slope K1Comprises the following steps:
straight line segment d1The equation of (a) is: y is equal to K1(X-X1)+Y1
And (3) coordinate of midpoint O of connecting line of injection and production wells:
slope K of vertical line of injection well connecting line2Comprises the following steps:
the equation of the vertical line passing through the connecting line of the midpoint O and the injection and production well is obtained as follows: y is equal to K2(X-X0)+Y0
Order: straight line segment d1The coordinate of the intersection point T of the cross-midpoint O and the perpendicular line connecting the injection and production well is (X)T,YT) Thereby obtaining:
YT＝K1(XT-X1)+Y1or YT＝K2(XT-X0)+Y0
By the T coordinate being (X)T,YT) And calculating to obtain:
(2) injection-production streamline approximate calculation method based on linear model
For the straight line model, as shown in FIG. 3, any point P (X) between injection wells and production wells is directly calculatedp，Yp) To water injection well Inj (X)1，Y1) Distance d of1And to production well Pro (X)2，Y2) Distance d of2The method is faster than the diamond model in calculation speed.
Step 2: streamline winding fault calculation method based on linear model
For a fault block oil deposit, micro fault shielding may exist between an injection well and a production well, when fault extension is not enough to play a sealing role in an injection and production well flow field, injected water flows to the production well by bypassing fault end points to form an injected water bypassing fault phenomenon, specifically as shown in fig. 4, at the moment, for any point P in the oil deposit, streamline approximation can be carried out in two situations.
(1) The P1 point is at the position between the water injection well and the fracture layer
The streamline can flow to the fault end points through two ways, namely Inj-M1-A and I-M1-B, since ∠ I-M1-A is smaller than 90 degrees, the streamline is not possible to exist in practice, and the simplified path mode of the M1 point at the position between the water injection well and the fault can be approximated by Inj-M1-B-Pro, so that the streamline of the water injection well Inj which is shielded by the fault and the streamline of the production well Pro are determined to meet the following conditions:
①∠Inj-M1-B>90°
②∠M1-B-Pro>90°
③Dis(Inj-M1-B-Pro)＝d01+d02+d1<Dmax
wherein: dis (Inj-M1-B-Pro) is the length of the Inj-M1-B-Pro path; dmax is 2 times of the control radius of the injection and production well of the test well.
(2) The P2 point is at the position between the producing well and the fracture
For one side of the production well, the streamline can flow to a Pro point of the production well through two ways, namely Inj-A-M2-Pro and Inj-B-M2-Pro, since ∠ Pro-M2-B is smaller than 90 degrees, the streamline cannot exist in practice, and the simplified path mode of the M2 point at the position between the production well and the fault can be approximated by Inj-A-M2-Pro, so that the streamline of the water injection well I and the streamline of the production well P subjected to fault shielding effect can meet the following conditions:
①∠Pro-M2-A>90°
②∠M2-A-Inj>90°
③Dis(Inj-A-M2-Pro)＝d0+d11+d12<Dmax
and step 3: method for calculating correction factor C of streamline curvature to speed based on diameter expansion angles of arc length model, linear model and diamond model
(1) Principle of macroscopic curvature correction
The flow tube unit body model in the process of the planar seepage flow diagram 5 can be expressed as the gradual change type elbow flow shown in fig. 6, and the gradual change type elbow flow can be decomposed into: the equal diameter elbow flowing process, the gradual expanding flowing process and the gradual reducing flowing process.
① for equal diameter elbow flow process
The water flows in the elbow, the flowing direction is changed, the speed is unchanged, the head loss coefficient generated by the elbow depends on the angle theta of the elbow and the ratio of the curvature radius to the pipe diameter, and the common resistance coefficient expression of the elbow is as follows:
wherein ξ is resistance coefficient, R and R are bend radius and curvature radius, and α is bend angle.
For the calculation of the resistance coefficient of the elbow at 180 degrees, the resistance coefficient of the right-angle elbow can be approximately calculated by 2 times.
② for divergent flow process
The expression for the divergent pipe local head loss coefficient ξ is calculated as:
in the formula: lambda is the coefficient of on-way friction resistance, for laminar flow,
v is the flow velocity, m/s; d is the inner diameter, m; theta is the expanding angle; a. the1、A2The cross section area of the inlet and the outlet;
③ for tapered flow process
For the tapered flow process, the resistance coefficient does not change much, and ξ is generally equal to 0.04.
(2) Calculation of diameter expansion angle theta based on arc length model, linear model and diamond model
The calculation of the expanding angle theta can be carried out through a circular arc length model, a straight line model, three models and a diamond model, and the specific steps are as follows.
① circular arc length model
For the calculation of the diameter expansion angle theta of the circular arc length model, as shown in FIG. 7, the distance L between the two arcs is calculated3The calculation method of the expansion angle theta is set as the maximum width of the grid:
because: l is4＝R1-R1cosθ1-L3、
Because:
therefore: theta is equal to theta1-θ2
② straight line model
The calculation of the diameter expansion angle θ of the linear model is as shown in fig. 8, and the calculation process is as follows.
③ Diamond model
The calculation of the diamond model expansion angle θ is shown in fig. 9, and the calculation process is as follows.
It can be seen that the additional drag coefficients due to flow tube bending and flow tube tapering are:
(3) curvature correction factor C determination
The friction change ratio, i.e., the curvature correction coefficient C, is:
and 4, step 4: method for calculating correction factor M of injection-production included angle to speed
Under the control of the injection and production well pattern (A, B, C is a production well, D, E is a water injection well), as shown in fig. 10, the flow velocity of O at any point on the reservoir plane flow field is influenced by static parameters such as distance and reservoir physical properties, and is also related to the sizes of included angles ∠ AOD, ∠ BOD, ∠ COD, ∠ AOE, ∠ BOE and ∠ COE formed by the connecting line of the point and the water injection well and the production well, and it can be seen that:
(1) ∠ BOE and ∠ COE are both smaller than 90 degrees, and the visible O point is slightly influenced by well control between the water injection well E and the production well B, C and can be ignored;
(2) ∠ AOE is more than 90 degrees, and from the view of injection and production relation, the O point is controlled by the water injection well E and the production well A to have certain possibility;
(3) ∠ AOD, ∠ BOD and ∠ COD are all larger than 90 degrees, wherein ∠ BOD is ∠ COD is ∠ AOD, and the larger the angle is, the stronger the control capability is in view of the injection-production relationship;
therefore, when the included angle formed by any point O on the reservoir plane and the connecting line of the injection and production wells is smaller than 90 degrees, the control capability of the injection and production wells for the point can be ignored, when the included angle is larger than 90 degrees, the control capability is gradually increased along with the increase of the angle, when the angle is equal to 180 degrees, the point O is positioned on the main flow line, the control degree between the injection and production wells is strongest, and the flow field speed is higher.
Considering water injection sudden-entering and water injection transverse diffusion caused by the difference between the injection-production well connecting line and the vertical direction thereof, and obtaining a correction factor M of the injection-production included angle to the speed:
M＝(cosδ)n
in the formula: m is an included angle correction factor between injection wells and production wells; delta is an included angle formed by the connecting line of the point and the production well of the water injection well; n is the ratio of the permeability of the injection-production well connecting line to the permeability perpendicular to the direction on the plane.
And 5: method for calculating flow field velocity of injection-production well pattern
Known from the superposition principle of equal-yield multi-source convergence infinite plane radial flow potential, the velocity vector generated at any point O in the oil deposit corresponding to the ith well at the point is as follows:
preferably, in the step 5, the following four processes can be specifically divided:
process 1: heterogeneous model permeability calculation
For linear seepage, it is assumed that the flow direction is heterogeneous and the lengths are L1、L2、L3The thickness of the oil layer is h, and the permeability is K1、K2、K3And then:
total length of formation L ═ L1+L2+L3，ΔP＝ΔP1+ΔP2+ΔP3，Q＝Q1＝Q2＝Q3
According to the darcy formula:
the linear seepage average permeability K is obtained as follows:
and (2) a process: calculation of injection-production differential pressure
(1) Injection-production differential pressure calculation at given bottom hole pressure
Δpij＝pInj-ij-ppro-ij
(2) Injection-production differential pressure calculation under given injection-production liquid volume
In the formula: subscript Inji、projParameters around a water injection well i and a production well j are respectively, and a is an oil drainage radius.
(3) Injection-production differential pressure calculation under given meter injection-production liquid quantity
(4) Determination of drainage radius a
The oil drainage radius of the oil-water well is calculated by adopting an infinite stratum plane radial flow Darcy formula:
through oil and gas well testing, at specific permeability k 'and a', calculating specific pressure drop Δ p ', and then proportionally correcting the specific pressure drop Δ p' to the corresponding total pressure drop at a → ∞ where ∞ can be set to a specific value such as 5000 m; and then correcting the pressure drop according to the actual conditions k and h of each well to obtain the actual pressure drop delta p under the actual injection and production liquid volume of each single well at present, wherein the pressure drop is delta pMij。
And 3, process: o-point injection production well network flow field velocity calculation
The vector velocity formed by the corresponding i, j well of point O is:
in the formula: i is the water injection well number corresponding to the O point; j is the number of the production well corresponding to the O point; cijA macroscopic curvature correction coefficient corresponding to the O point;
the average permeability of the track corresponding to the O point is obtained; a isijFor water injection well i and production wellThe distance between j;
the distances from the point O to the water injection well i and the production well j are respectively.
The flow field velocity vector superposition of the O point is as follows:
and 4, process: injection-production well pattern flow field speed calculation step
The specific steps of calculating the flow field velocity of the injection-production well pattern are as follows:
① selecting a mesh center point O according to the numerical simulation mesh division result and the well pattern control mode;
② searching the corresponding water injection well i and production well j;
③ calculating the locus of the point O and the water injection well i and the locus of the point O to the production well j by using the locus parameter model;
④ calculating average reservoir physical parameters such as thickness, permeability and saturation of the trajectory;
⑤ calculating the macroscopic curvature correction coefficient Cij；
⑥ calculating the influence correction coefficient (cos delta) of injection-production included angleMij)n；
⑦ repeatedly calculating the water drive strength of all water injection wells i and production wells j corresponding to the O points
⑧ calculating the vector sum of all the calculated vector flow field velocities to obtain the flow field velocity of the point;
⑨ repeating the ① - ⑧ process, calculating all grid nodes, and obtaining the injection-production well pattern flow field speed considering static parameters, well pattern form and injection-production dynamics.
Example two
In order to provide a more intuitive understanding of the application effect of the rapid calculation method for the flow field velocity of the injection-production well pattern provided in the first embodiment, a specific implementation manner of the present invention is described by taking a calculation process using the above method as an example.
For the triangular well pattern with one injection and two extraction, the heterogeneous model is designed by adopting different permeability ratios between injection wells and extraction wells, and the heterogeneous model is formed after interpolation, and the specific parameter ratio design is shown in Table 1
TABLE 1 one-injection two-production triangular well pattern heterogeneity design
| Heterogeneity | Model 1 | Model 2 | Model 3 |
| ④:③ | 400:400 | 550:250 | 700:100 |
Aiming at three models of one-injection two-extraction design, the unit division results of residual oil saturation, water drive strength and water drive degree when the water content reaches 98% are respectively calculated and are shown in figure 12, and it can be seen that when the permeability between a water injection well and a production well is large, after the water content of the well reaches 98%, an obvious water channeling channel is formed between the two wells, the flow field velocity is large, residual oil basically has no potential in the area between the water channeling wells, and the potential area is mainly concentrated in the area with small flow field velocity between the production wells and the area between non-water channeling wells.
The above-mentioned embodiments are intended to illustrate the objects, technical solutions and advantages of the present invention in further detail, and it should be understood that the above-mentioned embodiments are only exemplary embodiments of the present invention, and are not intended to limit the scope of the present invention, and any modifications, equivalent substitutions, improvements and the like made within the spirit and principle of the present invention should be included in the scope of the present invention.
Claims (6)
1. A rapid calculation method for the flow field velocity of an injection-production well network is characterized in that flow field distribution among injection-production wells is established according to an injection-production flow line approximate calculation method based on a diamond model and a linear model and a flow line fault-surrounding calculation method based on the linear model, a correction factor C calculation method for velocity by using the curvature of a flow line based on an arc length model, the linear model and a diamond model diameter expansion angle and a correction factor M calculation method for velocity by using an injection-production included angle are used for calculating a correction factor of the flow field velocity, and the flow field velocity calculation method is used for calculating the flow field velocity;
(1) the calculation method of the correction factor C comprises the following steps:
in the formula: lambda is the coefficient of on-way friction resistance, for laminar flow,
α is angle of bend, v is flow speed m/s, d is inner diameter m, theta is expanding angle A1、A2The cross section area of the inlet and the outlet; r and R are respectively the radius of the bent pipe and the radius of curvature;
(2) the calculation method of the correction factor M comprises the following steps:
M＝(cosδ)n
in the formula: m is an included angle correction factor between injection wells and production wells; delta is an included angle formed by the connecting line of the point and the production well of the water injection well; n is the ratio of the permeability of the injection-production well connecting line to the permeability in the vertical direction on the plane;
(3) the method comprises the following steps of:
① selecting a mesh center point O according to the numerical simulation mesh division result and the well pattern control mode;
② searching the corresponding water injection well i and production well j;
③ calculating the locus of the point O and the water injection well i and the locus of the point O to the production well j by using the locus parameter model;
④ calculating the average reservoir physical parameters of the trace, such as thickness, permeability and saturation;
⑤ calculate a curvature versus velocity correction factor Cij；
⑥ calculating the correction factor M of injection-production included angle to speed;
⑦ repeatedly calculating the flow field velocities of all water injection wells i and production wells j corresponding to the O points
Wherein: Δ pijIs the injection and production pressure difference, and a is the oil drainage radius;
is the average interpore permeability; μ is the fluid viscosity;
the distances from the point O to the water injection well i and the production well j are respectively; cijIs the correction factor C between the water injection well i and the production well j;
⑧ vector sum all the calculated flow field velocities to get the flow field velocity at this point:
⑨ repeating the ① - ⑧ process, calculating all grid nodes, and obtaining the injection-production well pattern flow field speed considering static parameters, well pattern form and injection-production dynamics.
2. The method according to claim 1, wherein the approximate calculation method of the injection-production flow line based on the diamond model and the straight line model comprises the following specific steps: the streamline generated by converging the equal-thickness infinite stratum and the equal-yield sources at any point P in the stratum is a group of circular arcs and is influenced by the calculation speed of the grid search process where the circular arc track is located, and the circular arc model is simplified into a rhombic model or a linear model formed by a water injection well, a point P and a production well, so that the streamline calculation time is shortened.
3. The method according to claim 1, characterized in that the streamline detour fault calculation method based on the straight line model is specifically as follows: when the fault length is not enough to form the injection-production packer effect, the phenomenon that injected water flows into a production well around the fault is formed, and for any point P between injection-production wells, the flow line calculation can be carried out under the two conditions that the point P and an injection well are positioned at the same side of the fault and the point P and the production well are positioned at the same side of the fault, and the calculation principle is that the flow line is approximately simulated by a broken line track formed by the injection well, the point P, the fault end point, the production well and the injection well, the fault end point, the point P and the production.
4. The method according to claim 1, wherein the calculation method of the correction factor C of streamline curvature to speed based on the arc length model, the straight line model and the diamond model expanding angle is specifically as follows: the flow pipe unit body model formed by the streamline can be expressed as the gradual change type elbow flow, the gradual change type elbow flow is decomposed into an equal-diameter elbow flow process, a gradual expansion type flow process and a gradual reduction type flow process again, the friction resistance of the three flow processes is calculated respectively, and the speed correction factor C is calculated.
5. The method according to claim 1, wherein the method for calculating the correction factor M of the injection-production included angle to the velocity specifically comprises: the flow field velocity of any point P on the reservoir plane is influenced by distance and reservoir physical property static parameters, and is also related to the size of an included angle formed by the point P and a connecting line of a water injection well and a production well, when the included angle of the connecting line is smaller than 90 degrees, the flow field velocity of the point between injection and production wells can be ignored, when the included angle is larger than 90 degrees, the velocity influence is increased along with the increase of the angle, when the angle is equal to 180 degrees, the point is positioned on a main flow line, the velocity influence is maximum, and therefore the power square of the cosine value of the angle is used as a velocity correction factor M of the injection and production included angle.
6. The method according to claim 1, wherein the injection-production differential pressure is calculated in three cases, namely, an injection-production differential pressure calculation method at a given bottom hole pressure, an injection-production differential pressure calculation method at a given injection-production fluid volume, and an injection-production differential pressure calculation method at a given injection-production fluid volume.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201710159951.7A CN106980758B (en) | 2017-03-17 | 2017-03-17 | Rapid calculation method for flow field velocity of injection-production well pattern |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201710159951.7A CN106980758B (en) | 2017-03-17 | 2017-03-17 | Rapid calculation method for flow field velocity of injection-production well pattern |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN106980758A CN106980758A (en) | 2017-07-25 |
| CN106980758B true CN106980758B (en) | 2020-06-26 |
Family
ID=59338274
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201710159951.7A Active CN106980758B (en) | 2017-03-17 | 2017-03-17 | Rapid calculation method for flow field velocity of injection-production well pattern |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN106980758B (en) |
Families Citing this family (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN108049849B (en) * | 2017-09-07 | 2019-11-29 | 中国石油化工股份有限公司 | Water-drive pool Plane Fluid Field regulates and controls design method |
| CN108868745B (en) * | 2018-07-09 | 2021-10-01 | 中国石油大学(华东) | Oil reservoir flow field matching evaluation method |
| CN109933899B (en) * | 2019-03-13 | 2023-04-25 | 中国石油大学(华东) | Method for determining water flooding old oilfield period water flooding development period calculation chart |
| CN110826171B (en) * | 2019-09-18 | 2023-04-18 | 深圳先进技术研究院 | Method and device for simulating external flow field of fan and computer readable storage medium |
| CN116341406B (en) * | 2023-03-03 | 2024-04-23 | 常州大学 | Calculation method for determining injection and production interference time of inclined oil reservoir |
Citations (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN1224848A (en) * | 1998-08-03 | 1999-08-04 | 辽河石油勘探局钻采工艺研究院 | Inter-well tracing determination technology using chemical tracer |
| CN101661514A (en) * | 2008-05-21 | 2010-03-03 | 中国石化股份胜利油田分公司地质科学研究院 | Oil deposit black oil model numerical simulation system |
| CN103970989A (en) * | 2014-04-15 | 2014-08-06 | 昆明理工大学 | Immersing boundary flow field calculation method based on fluid/solid interface consistency |
| CN105822271A (en) * | 2015-09-09 | 2016-08-03 | 中国石油化工股份有限公司 | Adjustment method of variable flow line vector of thick-stratum oil deposit |
-
2017
- 2017-03-17 CN CN201710159951.7A patent/CN106980758B/en active Active
Patent Citations (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN1224848A (en) * | 1998-08-03 | 1999-08-04 | 辽河石油勘探局钻采工艺研究院 | Inter-well tracing determination technology using chemical tracer |
| CN101661514A (en) * | 2008-05-21 | 2010-03-03 | 中国石化股份胜利油田分公司地质科学研究院 | Oil deposit black oil model numerical simulation system |
| CN103970989A (en) * | 2014-04-15 | 2014-08-06 | 昆明理工大学 | Immersing boundary flow field calculation method based on fluid/solid interface consistency |
| CN105822271A (en) * | 2015-09-09 | 2016-08-03 | 中国石油化工股份有限公司 | Adjustment method of variable flow line vector of thick-stratum oil deposit |
Non-Patent Citations (4)
| Title |
|---|
| Semi-analytical computation of path lines for finite-difference models;Pollock D W. et al;《Ground Water》;19881231;第26卷(第6期);743-750 * |
| Water Injection Optimization Using a Streamline-Based Workflow;Thiele M.R.et al;《Society of Petroleum Engineers》;20031231;1-10 * |
| 二维可视化水驱物理模拟井间参数解释方法;郭文敏等;《石油天然气学报（江汉石油学院学报）》;20111031;第33卷(第10期);125-131 * |
| 静观2区块高凝油油藏流动单元预测表征及剩余油分布研究;喻鹏;《中国博士学位论文全文数据库 工程科技Ⅰ辑》;20141115;第2014年卷(第11期);B019-4 * |
Also Published As
| Publication number | Publication date |
|---|---|
| CN106980758A (en) | 2017-07-25 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN106980758B (en) | Rapid calculation method for flow field velocity of injection-production well pattern | |
| CN102087130B (en) | Computational fluid dynamics (CFD) technology-based method for optimizing acoustic path of multi-path ultrasonic flowmeter assembled in elbow pipe | |
| CN106979918A (en) | A kind of method and device for the Test Liquid Permeability of Core for obtaining compact oil reservoir rock core | |
| CN103074873B (en) | Channel arrangement method of multichannel ultrasonic flow meter in nonideal flow field | |
| CN101881640A (en) | Vortex mass flow meter | |
| CN102031965B (en) | Oil-gas reservoir physical simulation wellbore radius processing method | |
| CN107843297B (en) | Low-gas-content gas-liquid two-phase flow liquid phase flow online measuring device and method based on V cone | |
| CN105138738B (en) | A kind of three-dimensional permeability tensor computational methods | |
| CN103940495A (en) | Small-flow ultrasonic flowmeter error estimation method based on flow lines | |
| CN104989385B (en) | The HTHP oil gas straight well perforating parameter optimization method calculated based on skin factor | |
| CN102630426B (en) | Structure optimization method for Venturi fertilizer injector | |
| Pandey et al. | Liquid–liquid two phase flow through a horizontal T-junction | |
| CN108876911B (en) | Calculation method and device for three-dimensional flow field of supersonic flow channel | |
| Zhang et al. | Experimental investigation of cavitation in a sudden expansion pipe | |
| CN105320790A (en) | Design method of throttle valve with pressure drop linearly changed with opening degree as well as valve core | |
| CN108506622B (en) | A kind of lower resistance threeway component based on arc flow deflector | |
| CN104897364B (en) | Method for determining gas-liquid two-phase hydrodynamic slug flow in horizontal and micro-inclined pipes | |
| CN115653570A (en) | Shaft-sliding sleeve-reservoir coupled flow inflow dynamic prediction method and system | |
| CN111997575B (en) | Irregular well pattern optimization water injection method based on planar displacement component | |
| CN111119815A (en) | Method for determining production well production allocation ratio through balanced displacement | |
| CN202421207U (en) | Seven-electrode array correlated conductive sensor for measuring flow speed | |
| Mark et al. | An analytical model for solute mixing in surcharged manholes | |
| CN110991084B (en) | Reservoir permeability calculation method based on streamline numerical value well test | |
| Xing et al. | Investigation of slug flow induced forces on pipe bends applying STAR-OLGA coupling | |
| CN105444828B (en) | The design method of the rectifier of ultrasonic flowmeter |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant |