CN111364955A - Method for simulating flow field evolution between injection wells and production wells - Google Patents
Method for simulating flow field evolution between injection wells and production wells Download PDFInfo
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- 238000004519 manufacturing process Methods 0.000 title claims abstract description 56
- 238000002347 injection Methods 0.000 title claims abstract description 54
- 239000007924 injection Substances 0.000 title claims abstract description 54
- 238000000034 method Methods 0.000 title claims abstract description 37
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 63
- 238000004088 simulation Methods 0.000 claims abstract description 18
- 230000035699 permeability Effects 0.000 claims description 26
- 239000012071 phase Substances 0.000 claims description 10
- 230000014509 gene expression Effects 0.000 claims description 9
- 239000002245 particle Substances 0.000 claims description 7
- 230000008569 process Effects 0.000 claims description 7
- 239000008346 aqueous phase Substances 0.000 claims description 3
- 238000004422 calculation algorithm Methods 0.000 claims description 3
- 238000004364 calculation method Methods 0.000 claims description 3
- 239000011148 porous material Substances 0.000 claims description 3
- 239000000126 substance Substances 0.000 claims description 3
- NAWXUBYGYWOOIX-SFHVURJKSA-N (2s)-2-[[4-[2-(2,4-diaminoquinazolin-6-yl)ethyl]benzoyl]amino]-4-methylidenepentanedioic acid Chemical compound C1=CC2=NC(N)=NC(N)=C2C=C1CCC1=CC=C(C(=O)N[C@@H](CC(=C)C(O)=O)C(O)=O)C=C1 NAWXUBYGYWOOIX-SFHVURJKSA-N 0.000 claims 1
- 239000011435 rock Substances 0.000 description 5
- 230000008901 benefit Effects 0.000 description 3
- 239000012530 fluid Substances 0.000 description 3
- 238000011084 recovery Methods 0.000 description 3
- 238000010586 diagram Methods 0.000 description 2
- 238000006073 displacement reaction Methods 0.000 description 2
- 239000003129 oil well Substances 0.000 description 2
- 230000008859 change Effects 0.000 description 1
- 239000003795 chemical substances by application Substances 0.000 description 1
- 125000004122 cyclic group Chemical group 0.000 description 1
- 239000006185 dispersion Substances 0.000 description 1
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- 230000007246 mechanism Effects 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/20—Displacing by water
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Abstract
The invention provides a method for simulating the flow field evolution among injection and production wells, which comprises the following steps: step 1, initializing a model; step 2, calculating a pressure gradient field; step 3, dividing flow channels; step 4, calculating the resistance of each flow channel; step 5, calculating the water injection amount of each flow channel; step 6, calculating the yield of each flow channel; and 7, updating the water saturation. The flow field evolution simulation method between injection wells and production wells can calculate the flow area of injected water in a plane space, effectively evaluate the position of residual oil and the water flooding wave and range, provide effective guidance for oil field production decision and have good application prospect in the development of high-water-cut oil reservoirs.
Description
Technical Field
The invention relates to the technical field of oilfield development, in particular to a flow field evolution simulation method between injection and production wells.
Background
At present, old oil fields in the east of China generally enter a high-water-content development stage, residual oil is scattered and complex in distribution, and development benefits gradually become worse along with rapid increase of water content. How to utilize the existing well pattern conditions to realize the benefit development of the residual oil needs to be deeply researched from the mechanism to guide the development practice. At present, there are several basic questions to be answered in the water flooding development process, for example, how well pattern adjustment is performed in many rounds in old oil fields with high water content, how much each well can control the local position of the oil reservoir? How large spread can be expanded by injection-production control alone? Which locations must be drilled to enable efficient exploitation?
The traditional reservoir engineering and numerical simulation methods lack effective simulation of production characteristics in the high water-cut stage of the oil field. In the application No.: the Chinese patent application 201710248830.X relates to a numerical simulation method for proppant embedment and quantitative prediction of fracture conductivity, which comprises the following steps: s1, establishing a physical model for reducing the real size of the proppant; s2, applying closing pressure to the surfaces of the upper rock stratum and the lower rock stratum of the model, wherein the difference of the average heights of fracture surface particles of the upper rock stratum and the lower rock stratum is fracture closing width w; s3, performing flow field grid dispersion on the filling layer to enable the flow field to wrap the propping agent, and setting the viscosity and density of fluid and the fluid pressure at two ends of the flow field; s4, calculating the total flow q of the flow field; s5, calculating permeability and conductivity; and S6, changing the physical parameters of the rock stratum or the fluid, and drawing a curve chart of the diversion capacity of the proppant with different sand laying concentrations along with the change of the closing stress. The patent provides a method for predicting fracture conductivity by combining physical simulation and numerical simulation, aims at the problem of predicting the fracture conductivity in an artificial reservoir transformation process, and does not belong to the development process of a high-water-cut water-drive reservoir. Therefore, a new method for simulating the flow field evolution between injection wells and production wells is invented, and the technical problems are solved.
Disclosure of Invention
The invention aims to provide a flow field evolution simulation method between injection and production wells, which can calculate the flow area of injected water in a plane space, effectively evaluate the position of residual oil and the water flooding wave range and provide effective guidance for oil field production decision.
The object of the invention can be achieved by the following technical measures: the method for simulating the flow field evolution between injection wells and production wells comprises the following steps: step 1, initializing a model; step 2, calculating a pressure gradient field; step 3, dividing flow channels; step 4, calculating the resistance of each flow channel; step 5, calculating the water injection amount of each flow channel; step 6, calculating the yield of each flow channel; and 7, updating the water saturation.
The object of the invention can also be achieved by the following technical measures:
the method for simulating the flow field evolution between the injection and production wells further comprises the steps of returning to the step 4 to recalculate the resistance of each flow channel after the step 7, and starting the cyclic calculation process of the steps 4-7 until the simulation time is finished.
In step 1, working parameters of oil deposit thickness, porosity, permeability, water saturation, relative permeability, injection and production well position, daily water injection quantity, daily oil recovery quantity, oil deposit pressure, bottom hole pressure and production time are obtained.
In the step 2, a pressure distribution and a pressure gradient vector field of each point in a space range are calculated and obtained by adopting a plane single-phase stable radial flow theoretical formula and a potential superposition principle formula according to the bottom pressure of the water injection well and the oil production well.
In step 3, the water well is taken as a starting point, N parts are divided according to 0-360 degrees, a particle tracking algorithm is adopted, each particle automatically searches for a path to reach the production well according to the pressure gradient field, and each path comprises a point set Pi[(x1，y1)，(x2，y2)，...，(xm，ym)]Whereby the entire space is divided into N flow channels, each channel path containing M points;
calculating the length l of each flow channel according to the formula (1)iThe pore volume V of each flow channel is calculated according to the expressions (2) and (3)i，；
Wherein S isi-the ith flow channel path is connected to the oil-water well (l)0) The area of the formed closed figure; h-reservoir thickness;
-reservoir average porosity.
In step 4, each flow passage resistance coefficient a is calculated from the expressions (4) and (5)i：
k′i＝∑(k1+k2+…+km)/M
(5)
Wherein, k'i-flow of the ithAverage permeability of the channel, i.e. set of points PiThe ith channel contains M points corresponding to the average permeability of each point.
In step 5, the water injection amount I of each flow channel is calculated according to the formula (6)i：
Wherein, ci-the water injection distribution coefficient of the ith flow channel, i.e. the percentage of water injection distributed in that flow channel; i iswDaily water injection.
In step 6, the flow channel production is calculated:
converting the relative permeability data into an oil phase flow rate coefficient f according to the formula (7)oi；
Wherein k isro-relative permeability of the oil phase; k is a radical ofrw-relative permeability of the aqueous phase; sw-water saturation;
calculating the oil production q of each flow channel according to the expressions (8) and (9)oiAdding to obtain the oil production q of the wello；
qoi＝Ii·ci·foi
(8)
qo＝∑qoi
(9)。
In step 7, the new water saturation for each flow channel is calculated according to equation (10):
wherein the content of the first and second substances,
-the water saturation at the time t,
water saturation at time t + 1.
The invention discloses a simulation method for flow field evolution between injection and production wells, and relates to a simulation method for flow field evolution between injection and production wells of a water-drive reservoir. The method starts from a basic seepage theory, divides a space into a plurality of flow channels according to the characteristics of an injection-production pressure system, and automatically distributes injected water among the flow channels in a difference mode according to the principle of low resistance priority. Different from the traditional streamline numerical simulation method, the method treats each flow channel as an average saturation, the simulation result can reflect the distribution difference of the injected water in the space, and the method is suitable for simulating the water flooding process under the long-term stable displacement condition.
Drawings
FIG. 1 is a flow chart of an embodiment of a simulation method of flow field evolution between injection wells and production wells of the present invention;
FIG. 2 is a schematic diagram of the pressure gradient between injection and production wells in an embodiment of the present invention;
FIG. 3 is a schematic diagram illustrating the flow channel division between injection wells and production wells according to an embodiment of the present invention.
Detailed Description
In order to make the aforementioned and other objects, features and advantages of the present invention comprehensible, preferred embodiments accompanied with figures are described in detail below.
As shown in fig. 1, fig. 1 is a flow chart of the simulation method for flow field evolution between injection wells and production wells of the present invention.
And 103, dividing the flow channel. Dividing the water well into N parts according to the angle of 0-360 degrees by taking the water well as a starting point, automatically searching paths for each particle to reach the production well according to the pressure gradient field by adopting a particle tracking algorithm, wherein each path comprises a point set Pi[(x1，y1)，(x2，y2)，...，(xm，ym)]Whereby the entire space is divided into N flow channels (fig. 3).
Calculating the length l of each flow channel according to the formula (1)iThe pore volume V of each flow channel is calculated according to the expressions (2) and (3)i。
Wherein S isi-the ith flow channel path is connected to the oil-water well (l)0) The area of the formed closed figure; h-reservoir thickness;
-reservoir average porosity.
k′i＝∑(k1+k2+…+km)/M
(5)
Wherein, k'iAverage permeability of the ith flow channel, i.e. set of points PiAverage value of permeability of each point.
And 105, calculating the water injection amount of each flow channel. Calculating the water injection quantity I of each flow channel according to the formula (6)i。
Wherein, ci-the water injection distribution coefficient of the ith flow channel, i.e. the percentage of water injection distributed in that flow channel; i iswDaily water injection.
Converting the relative permeability data into an oil phase flow rate coefficient f according to the formula (7)oi。
Wherein k isro-relative permeability of the oil phase; k is a radical ofrw-relative permeability of the aqueous phase; sw-water saturation;
calculating the oil production q of each flow channel according to the expressions (8) and (9)oiAdding to obtain the oil production q of the wello。
qoi＝Ii·ci·foi
(8)
qo＝∑qoi
(9)
Wherein the content of the first and second substances,
inclusion of time tThe degree of saturation of the water is,
water saturation at time t + 1.
In one embodiment of the present invention, the method comprises the following steps:
step 1, model initialization. According to the characteristics of geological oil reservoirs in a research area, oil well working parameters such as oil reservoir thickness, porosity, permeability, water saturation, relative permeability, injection and production well position, daily water injection quantity, daily oil recovery quantity, oil reservoir pressure, bottom hole pressure, production time and the like are set, and model initialization is completed.
And 2, calculating a pressure gradient field under a stable flowing condition according to the working parameters of the oil-water well set in the step 1, thereby obtaining a pressure gradient vector of each point in the research area (figure 2).
Step 3, taking the water injection well as a starting point, evenly dividing the range of 0-360 degrees into N parts, tracking the flow channel (figure 3) in each direction according to the pressure gradient field calculated in the step 2, and recording the position P of the path point of each channeliCalculating the path length l of each flow channeliAnd volume Vi。
Step 4, calculating the average permeability k 'of each path according to the positions of the path points obtained in the step 3'iAnd coefficient of resistance ai。
Step 5, calculating the water injection amount I of each flow channel according to the resistance coefficient obtained in the step 4i。
Step 6, calculating the oil phase flow rate coefficient f according to the relative permeability dataoiAnd further calculate the oil production q of each flow channeloiAnd the oil production q of the whole oil wello。
7, according to the oil production q of each flow channeloiCalculating the water saturation S after displacementw。
And 8, circulating the steps 4 to 7 until the simulation time is finished.
Claims (9)
1. The method for simulating the flow field evolution among the injection and production wells is characterized by comprising the following steps of:
step 1, initializing a model;
step 2, calculating a pressure gradient field;
step 3, dividing flow channels;
step 4, calculating the resistance of each flow channel;
step 5, calculating the water injection amount of each flow channel;
step 6, calculating the yield of each flow channel;
and 7, updating the water saturation.
2. The method for simulating the flow field evolution between injection and production wells according to claim 1, further comprising, after step 7, returning to step 4 to recalculate the resistance of each flow channel and starting the loop calculation process of steps 4-7 until the simulation time is over.
3. The method for simulating the flow field evolution between injection and production wells according to claim 1, wherein in step 1, the working parameters of reservoir thickness, porosity, permeability, water saturation, relative permeability, injection and production well position, daily water injection amount, daily oil production amount, reservoir pressure, bottom hole pressure and production time are obtained.
4. The method for simulating the evolution of the flow field between injection wells and production wells according to claim 1, wherein in the step 2, the pressure distribution and the pressure gradient vector field of each point in the space range are calculated and obtained by adopting a plane single-phase stable radial flow theoretical formula and a potential superposition principle formula according to the bottom pressures of the injection wells and the production wells.
5. The method for simulating flow field evolution between injection and production wells according to claim 1, wherein in step 3, the water well is used as a starting point and the flow field evolution between injection and production wells is from 0 ° to 360 °Dividing into N parts, and automatically finding paths for each particle to reach the production well according to the pressure gradient field by adopting a particle tracking algorithm, wherein each path comprises a point set Pi[(x1，y1)，(x2，y2)，...，(xm，ym)]Whereby the entire space is divided into N flow channels, each channel path containing M points;
calculating the length l of each flow channel according to the formula (1)iThe pore volume V of each flow channel is calculated according to the expressions (2) and (3)i，；
Wherein S isi-the ith flow channel path is connected to the oil-water well (l)0) The area of the formed closed figure; h-reservoir thickness;
-average reservoir porosity.
6. The method for simulating flow field evolution between injection and production wells according to claim 5, wherein in step 4, the resistance coefficient a of each flow channel is calculated according to the expressions (4) and (5)i：
k′i＝∑(k1+k2+…+km)/M (5)
Wherein, k'iAverage permeability of the ith flow channel, i.e. set of points PiThe ith channel contains M points corresponding to the average permeability of each point.
7. The method for simulating flow field evolution between injection and production wells according to claim 6, wherein in step 5, the water injection amount I of each flow channel is calculated according to the formula (6)i：
Wherein, ci-the water injection distribution coefficient of the ith flow channel, i.e. the percentage of water injection distributed in the flow channel; i isw-daily water injection.
8. The method for simulating flow field evolution between injection and production wells according to claim 7, wherein in step 6, the yield of each flow channel is calculated:
converting the relative permeability data into an oil phase flow rate coefficient f according to the formula (7)oi；
Wherein k isro-relative permeability of the oil phase; k is a radical ofrw-relative permeability of the aqueous phase; sw-water saturation;
calculating the oil production q of each flow channel according to the expressions (8) and (9)oiAdding to obtain the oil production q of the wello；
qoi＝Ii·ci·foi
(8)
qo＝∑qoi
(9)。
9. The method for simulating flow field evolution between injection and production wells according to claim 8, wherein in step 7, the new water saturation of each flow channel is calculated according to the formula (10):
wherein the content of the first and second substances,
-the water saturation at the time t,
water saturation at t +1 inch.
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| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN114200083A (en) * | 2021-12-07 | 2022-03-18 | 中海石油(中国)有限公司 | Chemical oil displacement full-process physical simulation device and method |
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| CN104453834A (en) * | 2014-10-31 | 2015-03-25 | 中国石油化工股份有限公司 | Injection-production relation optimizing and adjusting method for well group |
| CN108868745A (en) * | 2018-07-09 | 2018-11-23 | 中国石油大学(华东) | A kind of oil reservoir flow field matching evaluation method |
| CN110363325A (en) * | 2019-05-06 | 2019-10-22 | 中国石油化工股份有限公司 | Complex Fault Block Oil Reservoir multiple target note adopts optimising and adjustment method |
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Patent Citations (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| WO2003010415A1 (en) * | 2001-07-26 | 2003-02-06 | Ashis Kumar Das | Vertical flood for crude oil recovery |
| CN102913233A (en) * | 2012-11-03 | 2013-02-06 | 中国石油大学(华东) | Method for recognizing dominant flow channel based on zero dimension comparison plate |
| CN104453834A (en) * | 2014-10-31 | 2015-03-25 | 中国石油化工股份有限公司 | Injection-production relation optimizing and adjusting method for well group |
| CN108868745A (en) * | 2018-07-09 | 2018-11-23 | 中国石油大学(华东) | A kind of oil reservoir flow field matching evaluation method |
| CN110363325A (en) * | 2019-05-06 | 2019-10-22 | 中国石油化工股份有限公司 | Complex Fault Block Oil Reservoir multiple target note adopts optimising and adjustment method |
Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN114200083A (en) * | 2021-12-07 | 2022-03-18 | 中海石油(中国)有限公司 | Chemical oil displacement full-process physical simulation device and method |
| CN114200083B (en) * | 2021-12-07 | 2024-02-23 | 中海石油(中国)有限公司 | Chemical agent oil displacement whole-flow physical simulation device and method |
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