CN114165217A - Method and device for determining effective permeability, computer equipment and storage medium - Google Patents
Method and device for determining effective permeability, computer equipment and storage medium Download PDFInfo
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Abstract
The application provides a method and a device for determining effective permeability, computer equipment and a storage medium, and belongs to the technical field of oilfield development. This application is through the injection stratum information who obtains a plurality of injection stratums, because an injection stratum is corresponding to an injection stratum information, including being used for carrying out the multiple information that effective permeability confirms in the injection stratum information moreover, carry out the confirming of horizon coordinate, horizon injection pressure, injection stratum injection flow based on injection stratum information, and then can confirm the effective permeability of each injection stratum respectively, improve the definite accuracy of effective permeability.
Description
Technical Field
The application relates to the technical field of oilfield development, in particular to a method and a device for determining effective permeability, computer equipment and a storage medium.
Background
The ultimate goal of field development is to increase the ultimate recovery rate, while the recovery rate of primary recovery is very limited, so that further recovery of the field is required to increase the ultimate recovery rate by secondary and tertiary recovery. However, for medium and high permeability oil reservoirs, after a water well is injected with water for a long time, the permeability of part of production layers is changed greatly, even a dominant seepage channel is formed, and then a water cone phenomenon is formed, so that the water injection swept volume is reduced, and at this time, the effective permeability needs to be determined so as to adjust measures such as water injection, injection polymer flooding and the like according to the effective permeability.
At present, when the effective permeability of a reservoir is determined, the effective permeability is mainly obtained through calculation and measurement of a well testing method. However, in the implementation process, the average effective permeability of each injection layer of the injection well can only be determined by the well testing method, and is used as the effective permeability of each injection layer of the injection well, so that the accuracy of determining the effective permeability is low.
Disclosure of Invention
The embodiment of the application provides a method and a device for determining effective permeability, computer equipment and a storage medium, and the determination accuracy of the effective permeability can be improved. The technical scheme is as follows:
in one aspect, a method for determining effective permeability is provided, the method comprising:
acquiring injection layer information of a plurality of injection layers, wherein the injection layer information comprises geodetic coordinate information, layer top depth information, layer bottom depth information, injection mode information, injection pressure information and injection quantity information;
determining a horizon coordinate according to the geodetic coordinate information, the layer top depth information and the layer bottom depth information;
determining the horizon injection pressure according to the horizon coordinate, the injection mode information, the injection pressure information, the layer top depth information, the layer bottom depth information, the injection amount information and the static pressure;
determining the injection flow of an injection layer according to the injection amount information;
determining effective permeability of the plurality of injection zones based on the zone injection pressure and the injection zone injection flow rate.
In one possible implementation, after determining horizon coordinates according to the geodetic coordinate information, the top-of-layer depth information, and the bottom-of-layer depth information, the method further includes:
and if the injection layer information comprises well deviation data information, correcting the position coordinate according to the well deviation data information to obtain a corrected position coordinate.
In one possible implementation, the determining the horizon injection pressure based on the horizon coordinates, the injection mode information, the injection pressure information, the top of layer depth information, the bottom of layer depth information, the injection quantity information, and the static pressure comprises:
determining wellhead injection pressure according to the injection mode information and the injection pressure information;
and determining the horizon injection pressure according to the wellhead injection pressure, the horizon coordinate, the horizon top depth information and the horizon bottom depth information.
In one possible implementation manner, the injection manner corresponding to the injection manner information comprises a forward injection and a backward injection, and the injection pressure information comprises oil pressure information and casing pressure information;
should according to this injection mode information and this injection pressure information, confirm well head injection pressure and include:
if the injection mode corresponding to the injection mode information is positive injection, determining the oil pressure information as the wellhead injection pressure;
and if the injection mode corresponding to the injection mode information is the reverse injection, determining the casing pressure information as the wellhead injection pressure.
In one possible implementation, the determining the horizon injection pressure from the wellhead injection pressure, the horizon coordinate, the top of layer depth information, and the bottom of layer depth information comprises:
determining the pressure loss of the process according to the injection amount information;
determining the pressure of the water column according to the layer top depth information and the layer bottom depth information;
determining the static pressure according to the position coordinate;
and determining the horizon injection pressure according to the process pressure loss, the wellhead injection pressure, the water column pressure and the static pressure.
In one possible implementation, the determining the process pressure loss according to the injection amount information includes:
determining the on-way pressure loss and the local head loss according to the injection amount information;
and determining the sum of the on-way pressure loss and the local head loss as the on-way pressure loss sum.
In one possible implementation, the determining the water column pressure according to the layer top depth information and the layer bottom depth information includes:
the water column pressure is determined according to the following formula:
PW＝(h1+h2)/200；
wherein ,PWIs the pressure of the water column, h1For the layer top depth information, h2Is the layer bottom depth information.
In one possible implementation, the determining the static pressure from the horizon coordinate comprises:
for any injection layer in the plurality of injection layers, if the injection layer information of the any injection layer comprises the static pressure, acquiring the static pressure from the injection layer information of the any injection layer;
if the injection layer information of any injection layer does not include the static pressure, determining the static pressure of any injection layer according to the static pressure included in the injection layer information of the plurality of injection layers;
and if the injection layer information of the plurality of injection layers does not include the static pressure, determining the static pressure of any injection layer according to the injection-production ratio information included in the injection layer information of the plurality of injection layers.
In one possible implementation, the determining the horizon injection pressure from the process pressure loss and the wellhead injection pressure, the water column pressure, the static pressure comprises:
the horizon injection pressure is determined according to the following formula:
PWER＝P0-hf+PW-PR；
wherein ,PWERInjecting pressure, P, into the horizon0Injecting pressure h into the well headfFor the process loss of pressure and PWIs the pressure of the water column, PRIs the static pressure.
In one possible implementation, the determining the injection layer injection flow rate according to the injection amount information includes:
if the injection amount information is injection amount information of an injection layer, determining the injection amount information as injection flow of the injection layer;
and if the injection amount information is well injection amount information, determining the injection flow of the injection layer according to the injection amount information and relative injection amount information, wherein the relative injection amount information is used for indicating the flow lost by flowing through each injection layer.
In one possible implementation, the determining the effective permeability of the plurality of injection layers based on the horizon injection pressure and the injection layer injection flow rate comprises:
determining the effective permeability of the plurality of injection layers according to the following formula:
wherein q is the injection flow rate of the injection layer, B is the volume coefficient of the injection well, mu is the viscosity of the injection medium, and RETo supply radius, RWIs the well radius, S is the injection well skin factor, h is the injection horizon injection thickness, PRFor the static pressure, PWFRPressure is injected for that horizon.
In a possible implementation manner, the injection layer information further includes injection well number information, test date information, layer number information, layer injection strength information, belonging oilfield information, the block information, and injection medium information.
In one aspect, an apparatus for determining effective permeability is provided, the apparatus comprising:
the device comprises an acquisition module, a processing module and a processing module, wherein the acquisition module is used for acquiring injection layer information of a plurality of injection layers, and the injection layer information comprises geodetic coordinate information, layer top depth information, layer bottom depth information, injection mode information, injection pressure information and injection quantity information;
the first determining module is used for determining a horizon coordinate according to the geodetic coordinate information, the layer top depth information and the layer bottom depth information;
the second determining module is used for determining the horizon injection pressure according to the horizon coordinate, the injection mode information, the injection pressure information, the horizon top depth information, the horizon bottom depth information, the injection amount information and the static pressure;
the third determining module is used for determining the injection flow of the injection layer according to the injection amount information;
a fourth determination module to determine effective permeabilities of the plurality of injection zones based on the zone injection pressure and the injection zone injection flow rate.
In one possible implementation, the apparatus further includes:
and the correction module is used for correcting the position coordinate according to the well deviation data information to obtain a corrected position coordinate if the injection layer information comprises the well deviation data information.
In one possible implementation, the second determining module includes a first determining submodule and a second determining submodule;
the first determining submodule is used for determining wellhead injection pressure according to the injection mode information and the injection pressure information;
the second determining submodule is used for determining the horizon injection pressure according to the wellhead injection pressure, the horizon coordinate, the horizon top depth information and the horizon bottom depth information.
In one possible implementation manner, the injection manner corresponding to the injection manner information comprises a forward injection and a backward injection, and the injection pressure information comprises oil pressure information and casing pressure information;
the first determining submodule is used for determining the oil pressure information as the wellhead injection pressure if the injection mode corresponding to the injection mode information is positive injection, and determining the casing pressure information as the wellhead injection pressure if the injection mode corresponding to the injection mode information is reverse injection.
In a possible implementation manner, the second determining submodule includes a first determining unit, a second determining unit, a third determining unit, and a fourth determining unit;
the first determining unit is used for determining the process pressure loss and the sum of the injection amount information;
the second determining unit is used for determining the water column pressure according to the layer top depth information and the layer bottom depth information;
the third determining unit is used for determining the static pressure according to the position coordinate;
and the fourth determining unit is used for determining the horizon injection pressure according to the process pressure loss, the wellhead injection pressure, the water column pressure and the static pressure.
In one possible implementation, the second determining unit is configured to determine the water column pressure according to the following formula:
PW＝(h1+h2)/200；
wherein ,PWIs the pressure of the water column, h1For the layer top depth information, h2Is the layer bottom depth information.
In a possible implementation manner, the third determining unit is configured to, for any injection layer in the plurality of injection layers, obtain the static pressure from the injection layer information of the any injection layer if the injection layer information of the any injection layer includes the static pressure; if the injection layer information of any injection layer does not include the static pressure, determining the static pressure of any injection layer according to the static pressure included in the injection layer information of the plurality of injection layers; and if the injection layer information of the plurality of injection layers does not include the static pressure, determining the static pressure of any injection layer according to the injection-production ratio information included in the injection layer information of the plurality of injection layers.
In a possible implementation, the fourth determining unit is configured to determine the horizon injection pressure according to the following formula:
PWER＝P0-hf+PW-PR；
wherein ,PWERInjecting pressure, P, into the horizon0Injecting pressure h into the well headfFor the process loss of pressure and PWIs the pressure of the water column, PRIs the static pressure.
In a possible implementation manner, the third determining module is configured to determine, if the injection amount information is injection amount information of an injection layer, the injection amount information as an injection flow of the injection layer; and if the injection amount information is well injection amount information, determining the injection flow of the injection layer according to the injection amount information and relative injection amount information, wherein the relative injection amount information is used for indicating the flow lost by flowing through each injection layer.
In one possible implementation, the fourth determining module is configured to determine the effective permeability of the plurality of injection layers according to the following formula:
wherein q is the injection flow rate of the injection layer, B is the volume coefficient of the injection well, mu is the viscosity of the injection medium, and RETo supply radius, RWIs the well radius, S is the injection well skin factor, h is the injection horizon injection thickness, PRFor the static pressure, PWERPressure is injected for that horizon.
In a possible implementation manner, the injection layer information further includes injection well number information, test date information, layer number information, layer injection strength information, belonging oilfield information, the block information, and injection medium information.
In one aspect, a computer device is provided that includes one or more processors and one or more memories having at least one program code stored therein, the program code being loaded and executed by the one or more processors to implement the operations performed by the effective permeability determination method.
In one aspect, a computer-readable storage medium having at least one program code stored therein is provided, the program code being loaded into and executed by a processor to implement the operations performed by the effective permeability determining method.
In an aspect, a computer program product or a computer program is provided, the computer program product or the computer program comprising computer program code, the computer program code being stored in a computer readable storage medium. The processor of the computer device reads the computer program code from the computer-readable storage medium, and the processor executes the computer program code to perform the operations performed by the effective permeability determination method.
The scheme that this application provided, through the injection stratum information that obtains a plurality of injection stratums, because an injection stratum is corresponding to an injection stratum information, including being used for carrying out the multiple information that effective permeability confirms in the injection stratum information moreover, carry out the location coordinate, level injection pressure, the injection stratum injection flow volume's of injection on the basis of injection stratum information and confirm, and then can confirm the effective permeability on each injection stratum respectively, improve the definite accuracy of effective permeability.
Drawings
In order to more clearly illustrate the technical solutions in the embodiments of the present application, the drawings needed to be used in the description of the embodiments are briefly introduced below, and it is obvious that the drawings in the following description are only some embodiments of the present application, and it is obvious for those skilled in the art to obtain other drawings based on these drawings without creative efforts.
FIG. 1 is a flow chart of a method for determining effective permeability provided by an embodiment of the present application;
FIG. 2 is a flow chart of a method for determining effective permeability provided by an embodiment of the present application;
FIG. 3 is a schematic structural view of a water distributor provided by an embodiment of the present application;
FIG. 4 is a schematic diagram of a pipe string for a zonal injection well according to an embodiment of the present disclosure;
FIG. 5 is a schematic structural view of a water distributor and a water nozzle provided in the embodiments of the present application;
FIG. 6 is a flow chart of a partial head loss test of a water distributor provided by an embodiment of the present application;
FIG. 7 is a schematic structural diagram of an experimental main body provided in an embodiment of the present application;
FIG. 8 is a graphical illustration of a PS-114-46-20 water distribution nozzle provided in the embodiments of the present application;
FIG. 9 is a graphical illustration of the nozzle tip damage of a KGD-110 water distributor as provided in accordance with an embodiment of the present application;
FIG. 10 is a graphical illustration of KPX-114 distributor nozzle tip damage according to embodiments of the present application;
FIG. 11 is an apparatus for determining effective permeability provided by an embodiment of the present application;
fig. 12 is a schematic structural diagram of a computer device according to an embodiment of the present application.
Detailed Description
To make the objects, technical solutions and advantages of the present application more clear, embodiments of the present application will be described in further detail below with reference to the accompanying drawings.
The embodiment of the application provides a method for determining effective permeability in the technical field of oilfield development, and the method is specifically used for analyzing and calculating the real-time effective permeability of a single layer of an injection well by using injection profile logging information, providing an analysis and early warning scene for analyzing the formation of a dominant seepage channel, analyzing the space distribution of the effective permeability of each layer (well), constructing a seepage field, providing an analysis method and a scene of basis for oilfield development dynamic analysis and oil reservoir physical property analysis, and the like. Related technicians acquire logging data of an oil well through logging equipment, the acquired logging data are uploaded to computer equipment, and the logging data are stored by the computer equipment and serve as injection layer information of each injection layer in the oil well. In addition, the effective permeability of each injection layer is determined by the relevant technician through computer equipment based on the scheme provided in the application.
Fig. 1 is a flowchart of a method for determining effective permeability according to an embodiment of the present application, and referring to fig. 1, the method includes:
101. the computer device obtains injection layer information of a plurality of injection layers, wherein the injection layer information comprises geodetic coordinate information, layer top depth information, layer bottom depth information, injection mode information, injection pressure information and injection amount information.
102. The computer device determines horizon coordinates based on the geodetic coordinate information, the top-of-layer depth information, and the bottom-of-layer depth information.
103. And the computer equipment determines the horizon injection pressure according to the horizon coordinate, the injection mode information, the injection pressure information, the layer top depth information, the layer bottom depth information, the injection amount information and the static pressure.
104. And the computer equipment determines the injection flow of the injection layer according to the injection amount information.
105. A computer device determines effective permeability of the plurality of injection layers based on the horizon injection pressure and the injection layer injection flow rate.
According to the scheme provided by the embodiment of the application, the injection layer information of a plurality of injection layers is obtained, because one injection layer corresponds to one injection layer information, the injection layer information comprises various information used for determining the effective permeability, the determination of the position coordinate, the position injection pressure and the injection flow of the injection layer is carried out based on the injection layer information, the effective permeability of each injection layer can be determined respectively, and the determination accuracy of the effective permeability is improved.
In one possible implementation, after determining horizon coordinates according to the geodetic coordinate information, the top-of-layer depth information, and the bottom-of-layer depth information, the method further includes:
and if the injection layer information comprises well deviation data information, correcting the position coordinate according to the well deviation data information to obtain a corrected position coordinate.
In one possible implementation, the determining the horizon injection pressure based on the horizon coordinates, the injection mode information, the injection pressure information, the top of layer depth information, the bottom of layer depth information, the injection quantity information, and the static pressure comprises:
determining wellhead injection pressure according to the injection mode information and the injection pressure information;
and determining the horizon injection pressure according to the wellhead injection pressure, the horizon coordinate, the horizon top depth information and the horizon bottom depth information.
In one possible implementation manner, the injection manner corresponding to the injection manner information comprises a forward injection and a backward injection, and the injection pressure information comprises oil pressure information and casing pressure information;
should according to this injection mode information and this injection pressure information, confirm well head injection pressure and include:
if the injection mode corresponding to the injection mode information is positive injection, determining the oil pressure information as the wellhead injection pressure;
and if the injection mode corresponding to the injection mode information is the reverse injection, determining the casing pressure information as the wellhead injection pressure.
In one possible implementation, the determining the horizon injection pressure from the wellhead injection pressure, the horizon coordinate, the top of layer depth information, and the bottom of layer depth information comprises:
determining the pressure loss of the process according to the injection amount information;
determining the pressure of the water column according to the layer top depth information and the layer bottom depth information;
determining the static pressure according to the position coordinate;
and determining the horizon injection pressure according to the process pressure loss, the wellhead injection pressure, the water column pressure and the static pressure.
In one possible implementation, the determining the process pressure loss according to the injection amount information includes:
determining the on-way pressure loss and the local head loss according to the injection amount information;
and determining the sum of the on-way pressure loss and the local head loss as the on-way pressure loss sum.
In one possible implementation, the determining the water column pressure according to the layer top depth information and the layer bottom depth information includes:
the water column pressure is determined according to the following formula:
PW＝(h1+h2)/200；
wherein ,PWIs the pressure of the water column, h1For the layer top depth information, h2Is the layer bottom depth information.
In one possible implementation, the determining the static pressure from the horizon coordinate comprises:
for any injection layer in the plurality of injection layers, if the injection layer information of the any injection layer comprises the static pressure, acquiring the static pressure from the injection layer information of the any injection layer;
if the injection layer information of any injection layer does not include the static pressure, determining the static pressure of any injection layer according to the static pressure included in the injection layer information of the plurality of injection layers;
and if the injection layer information of the plurality of injection layers does not include the static pressure, determining the static pressure of any injection layer according to the injection-production ratio information included in the injection layer information of the plurality of injection layers.
In one possible implementation, the determining the horizon injection pressure from the process pressure loss and the wellhead injection pressure, the water column pressure, the static pressure comprises:
the horizon injection pressure is determined according to the following formula:
PWER＝P0-hf+PW-PR；
wherein ,PWERInjecting pressure, P, into the horizon0Injecting pressure h into the well headfFor the process loss of pressure and PWIs the pressure of the water column, PRIs the static pressure.
In one possible implementation, the determining the injection layer injection flow rate according to the injection amount information includes:
if the injection amount information is injection amount information of an injection layer, determining the injection amount information as injection flow of the injection layer;
and if the injection amount information is well injection amount information, determining the injection flow of the injection layer according to the injection amount information and relative injection amount information, wherein the relative injection amount information is used for indicating the flow lost by flowing through each injection layer.
In one possible implementation, the determining the effective permeability of the plurality of injection layers based on the horizon injection pressure and the injection layer injection flow rate comprises:
determining the effective permeability of the plurality of injection layers according to the following formula:
wherein q is the injection flow rate of the injection layer, B is the volume coefficient of the injection well, mu is the viscosity of the injection medium, and RETo supply radius, RWIs the well radius, S is the injection well skin factor, h is the injection horizon injection thickness, PRFor the static pressure, PWFRPressure is injected for that horizon.
In a possible implementation manner, the injection layer information further includes injection well number information, test date information, layer number information, layer injection strength information, belonging oilfield information, the block information, and injection medium information.
Fig. 2 is a method for determining effective permeability according to an embodiment of the present application, and referring to fig. 2, the method includes:
201. the computer device obtains injection layer information of a plurality of injection layers, wherein the injection layer information comprises geodetic coordinate information, layer top depth information, layer bottom depth information, injection mode information, injection pressure information and injection amount information.
The computer device stores injection layer information of a plurality of injection layers included in the plurality of injection wells, the injection layer information being log information of each injection profile of the well.
In more possible implementation manners, the injection layer information includes injection well number information, test date information, layer number information, layer injection strength information, affiliated oil field information, the block information, and injection medium information. Optionally, the injection layer information further includes other contents, which are not limited in this embodiment.
202. The computer device determines horizon coordinates based on the geodetic coordinate information, the top-of-layer depth information, and the bottom-of-layer depth information.
It should be noted that the geodetic coordinate information is the wellhead coordinate of the oil well corresponding to the injection layer, and therefore, after the geodetic coordinate information has been acquired, it is necessary to determine the depth information of the injection layer from the layer top depth information and the layer bottom depth information.
In a possible implementation manner, the computer device determines the layer top depth value corresponding to the layer top depth information and the average value of the layer bottom depth values corresponding to the layer bottom depth information as the depth information of the injection layer, and obtains the horizon coordinate of the injection layer by combining the ground coordinate information of the injection layer.
Optionally, if the information of the injection layer includes well deviation data information, the position coordinate is corrected according to the well deviation data information, and a corrected position coordinate is obtained and used as the position coordinate of the injection layer.
Wherein the well deviation data information is used to indicate the angle of inclination of the well. After determining the depth information of the injection layer, the computer equipment converts the depth information into depth information in the vertical direction according to the well deviation data information, and further obtains the horizon coordinate of the injection layer by combining the geodetic coordinate information of the injection layer.
203. And the computer equipment determines the wellhead injection pressure according to the injection mode information and the injection pressure information.
The injection method corresponding to the injection method information includes a forward injection and a reverse injection, and the injection pressure information includes oil pressure information and jacket pressure information.
In one possible implementation manner, if the injection manner corresponding to the injection manner information is a positive injection, the oil pressure information of the computer device is determined as the wellhead injection pressure.
In another possible implementation manner, if the injection manner corresponding to the injection manner information is a back injection, the computer device determines the casing pressure information as the wellhead injection pressure.
204. The computer device determines the horizon injection pressure based on the wellhead injection pressure, the horizon coordinates, the top of layer depth information, and the bottom of layer depth information.
In a possible implementation, the computer device determines a process pressure loss according to the injection amount information and a water column pressure according to the layer top depth information and the layer bottom depth information, determines the static pressure according to the layer position coordinate, and determines the layer position injection pressure according to the process pressure loss and the wellhead injection pressure, the water column pressure and the static pressure.
The calculation of the process pressure loss and, the water column pressure, the static pressure and the horizon injection pressure are described below:
flow pressure loss and
it should be noted that the oilfield injection wells can be classified into two categories, one is general injection and the other is stratified injection. The pressure loss of the flow from the two types of well heads to the horizon is different, and the pressure loss of the water nozzle is increased by layered injection. In the following, the calculation of the flow pressure loss sum will be described by taking the injection well as an example, and in the process of calculating the flow pressure loss sum of the injection well, whether to increase the mouth loss is determined according to the type of the injection well.
The pressure loss of the process from the well mouth to the horizon and the pressure loss including the process in the oil pipe, the diameter change, the water distributor and the like are generally 0.5-1MPa or ignored in the practical calculation, specifically taking the water injection well injected by layering as an example, the pressure loss in the process of injecting water into the stratum through the pipe column mainly comprises the process pressure loss and the local head loss, namely:
hf＝ΔP1+ΔP2 (1)
wherein ,hfFor process pressure loss and, Δ P1For on-way pressure loss, Δ P2Is the local head loss.
The on-way pressure loss and the local head loss of the water injection well with layered injection are respectively explained as follows:
wherein the on-way pressure loss is calculated by the following formula (2):
ΔP1＝ρgiL (2)
wherein ,ΔP1Rho is the liquid density (in kilograms per cubic meter, kg/m) for the on-way pressure loss (in megapascals, MPa)3) G is the acceleration of gravity (in meters per second squared, m/s)2) I is the pressure loss per unit length of the pipe (in meters per meter, m/m) and L is the length of the pipe (in meters per m).
The on-way pressure loss of steel pipelines and the like is as follows:
when v < 1.2m/s, i-0.000912 v2(1+0.867/v)0.3/d1.3 (3)
When v is more than or equal to 1.2m/s, i is 0.0017v2/d1.3 (4)
Wherein i is the pressure loss per unit length of the pipe (in meters per meter, m/m), v is the flow velocity of the liquid in the pipe (in meters per second, m/s), and d is the inner diameter of the pipe (in meters, m).
The on-way pressure loss calculation results are shown in table 1 below:
TABLE 1
As can be seen from the above table, the on-way pressure loss increases with the increase of the injection amount (i.e., the flow rate), but when the well depth reaches 4000m and the injection amount is 120m3/d, the on-way pressure loss is 0.3375MPa, and the water injection of the pipe column is basically not influenced. The on-way pressure loss of the water injection pipe column is calculated to be between 0.21 and 0.76MPa through analysis, and is basically consistent with theoretical calculation.
The local head loss mainly comprises the pressure loss of a bridge type eccentric water distributor, the pressure loss of a water flow injection process into a bottom layer and the like.
The structure of the bridge type eccentric water distributor and a formula for calculating the local head loss are introduced firstly as follows:
the bridge type eccentric water distributor mainly comprises an eccentric main body, a connecting mechanism, a centering guide mechanism, a water distribution plug and the like, and the specific structure is shown in fig. 3, wherein fig. 3 is a schematic structural diagram of the water distributor provided by the embodiment of the application. The technical parameters of the bridge type eccentric water distributor are shown in the following table 2:
TABLE 2
Referring to fig. 4, fig. 4 is a schematic view of a tubular column of a zonal injection well provided in the embodiment of the present application, where the injected water enters a water distributor through an oil pipe, enters an oil jacket annulus after the flow rate is adjusted by a water nozzle, and changes in diameter at 5 positions are performed, respectively: the water distributor, the lateral liquid inlet hole, the sand control cap, the water nozzle and the water outlet hole have local water head loss after diameter change every time. The variable diameter size at each position is respectively:
inner diameter of water distributor: phi 46mm (mm)
Lateral liquid inlet hole: phi 12mm
A sand prevention cap: 19mm 1.5mm 6+2mm 18
Water nozzle: 0-12mm
Water outlet hole: 19mm 5.5mm 3
Wherein, the actual replacement or adjustable range of the water nozzle is between 0 and 12 mm. The water nozzle is 12mm, wherein one condition is that the water nozzle is completely taken out, a circular channel with the position of 12mm is used for placing the water nozzle, the other condition is that a blanking plug is usually pulled out for amplifying water injection, water injection is directly carried out in a hollow core mode, and the minimum diameter-changing position of water flow is fixed to be a circular hole with the diameter of 12 mm. Based on the two conditions, when the nozzle loss range of the water nozzle is calculated, namely, the local water head loss of the water nozzle is calculated, the local water head loss corresponding to the variation relation between 0mm and 12mm is only required to be calculated.
The calculation formula of the local head loss is as follows:
wherein ,ΔP2The local head loss is shown as xi, the local head loss coefficient is shown as xi, the liquid density is shown as rho, and the liquid flow speed in the pipeline is shown as v.
After transformation, it can be expressed as:
wherein ,ΔP2The local head loss is shown as xi, the local head loss coefficient is shown as xi, the liquid density is shown as rho, the inner diameter of the pipeline is shown as d, and the injection flow of the injection layer is shown as q.
Based on the structure of the bridge type eccentric water distributor and a calculation formula of the local head loss, the local head loss corresponding to each structure is calculated according to the sequence of water flow flowing through each structure.
1. Water flow enters the bridge type eccentric water distributor from the oil pipe
The water flow enters the bridge type eccentric water distributor through the oil pipe, the diameter change is changed from 64mm to 46mm, the change range is small, the inner stroke of the water distributor is small, and therefore the local water head loss of the bridge type eccentric water distributor is negligible.
2. Water flow enters the side liquid inlet hole from the bridge type eccentric water distributor
And (3) entering a lateral liquid inlet hole from the eccentric water distributor, and determining the local head loss of the lateral liquid inlet hole according to a formula (5) when the diameter of the lateral liquid inlet hole is changed from 46mm to 12mm, wherein the determined result is shown in a table 3.
TABLE 3
3. Water flow enters the water nozzle from the side liquid inlet hole
The structure of water injection mandrel and water injection well choke refers to fig. 5, and fig. 5 is the schematic structural diagram of water injection mandrel and water injection well choke that this application embodiment provided, and the rivers flow through the side feed liquid hole and get into the water injection well choke and need pass through the sand control cap, and the reducing is bar hole and round hole respectively, and is more, and the rivers still have the reducing to the apopore after the water injection well choke in addition, utilize above single formula to have not carried out pressure loss calculation, consequently, need carry out the indoor test and obtain measured data. The test principle is as follows: the water in the liquid storage tank is pressurized by a plunger pump and then is sent to the experimental nuclear device, and flows back to the liquid storage tank after flowing through the water distributor, the water nozzle and the buffer tank. The test flow and the test main structure are respectively shown in fig. 6 and 7, fig. 6 is a local head loss test flow chart of the water distributor provided by the embodiment of the application, fig. 7 is a schematic diagram of the test main structure provided by the embodiment of the application, the flow is adjusted by adjusting a plunger pump valve, and each group of measured differential pressure data is obtained three times and averaged. Optionally, each set of measured differential pressure data is more, and then averaged, and the number of differential pressure data is not limited in the embodiment of the present application.
4. Damage of water distribution nozzle
The PS-114-46-20 water distribution nozzle curve plate is shown in figure 8, the KGD-110 water distribution nozzle damage curve plate is shown in figure 9, and the KPX-114 water distribution nozzle damage curve plate is shown in figure 10. And drawing a mouth loss curve from the water distributor to the water outlet according to the measured data, processing the test data, and obtaining the curves shown in the figures according to the variation range of the size of the water nozzle from 1.2mm to 8 mm. As can be seen from the analysis of the graph, the smaller the inner diameter of the water nozzle, the faster the nozzle loss increases with the gradually increasing injection amount. In addition, 60m is known from the nozzle damage plate of the water distributor3Loss of mouth per dayThe range is about 0.4-1 MPa.
Pressure of water column (II)
The water column pressure is determined according to the following equation (7):
PW＝(h1+h2)/200 (7)
wherein ,PWIs the pressure of the water column, h1For layer top depth information, h2Is the layer bottom depth information.
It should be noted that, when the water column pressure is calculated, the vertical depth correction is performed according to the well deviation data information, so as to ensure the accuracy of the determined water column pressure.
Static pressure of
It should be noted that static pressure refers to the bottom layer pressure of a layer, and when static pressure data is converted to a corresponding layer, vertical depth correction is required according to well deviation data during calculation; the data without static pressure is generally converted by using block or horizon accumulated injection-production ratio.
In one possible implementation manner, for any injection layer in the plurality of injection layers, if the injection layer information of the any injection layer includes the static pressure, the computer device obtains the static pressure from the injection layer information of the any injection layer.
In another possible implementation manner, for any injection layer in the plurality of injection layers, if the injection layer information of the any injection layer does not include the static pressure, the computer device determines the static pressure of the any injection layer according to the static pressure included in the injection layer information of the plurality of injection layers.
In another possible implementation manner, for any injection layer in the plurality of injection layers, if none of the injection layer information of the plurality of injection layers includes the static pressure, the computer device determines the static pressure of the any injection layer according to the injection-production ratio information included in the injection layer information of the plurality of injection layers.
(IV) horizon injection pressure
The horizon injection pressure is determined according to the following equation (8):
PWER＝P0-hf+PW-PR (8)
wherein ,PWERFor horizon injection pressure, P0Injection pressure, h, into the wellheadfFor process pressure loss and, PWIs the pressure of the water column, PRIs static pressure.
205. And the computer equipment determines the injection flow of the injection layer according to the injection amount information.
It should be noted that the injection profile data measurement method is divided into a quantitative measurement mode and a qualitative measurement mode, the flow of the quantitatively tested injection layer is directly quoted, and for the qualitative measurement data, the injection amount of the well needs to be matched with each injection layer according to the relative injection amount.
In one possible implementation, if the injection amount information is injection layer injection amount information, the computer device determines the injection amount information as the injection layer injection flow rate.
In another possible implementation manner, if the injection amount information is well injection amount information, the computer device determines the injection layer injection flow rate according to the injection amount information and relative injection amount information, wherein the relative injection amount information is used for indicating the flow rate lost by flowing through each injection layer, and for example, the relative injection amount information is the relative injection percentage of each layer. Namely:
injection flow rate of injection layer is well injection amount multiplied by relative injection percentage of each layer
206. A computer device determines effective permeability of the plurality of injection layers based on the horizon injection pressure and the injection layer injection flow rate.
According to the Darcy formula, the following formula (9) is obtained:
wherein q is the injection flow rate of the injection layer (unit is m)3D, the injection flow rate of the injection layer of the injection well is a negative value), B is the volume coefficient of the injection well (the volume coefficient of the injection well is 1), μ is the viscosity of the injection medium (in mPas, generally the viscosity of water is 0.5), REThe radius of the liquid supply (in m, because of the long-term stable water injection, the well spacing is generally 100-200m), RWIs the well radius (single)M, typically 0.0695m), S is the injection well skin factor (the injection well skin factor is typically zero), h is the injection thickness of the injection horizon (m), P isRIs static pressure, PWFRPressure is injected for the horizon.
From the above equation (9), equation (10) for determining the effective permeability of the plurality of implanted layers can be obtained:
the scheme that this application embodiment provided can dig the effect of a large amount of injection profile well logging data in oil field development deeply, promptly, utilizes Darcy's law to be used for effective permeability to calculate with the profile well logging data, and the practicality is strong, and easy programming is implemented, can replace the injection pressure drop test of segmentation in layers, extensively is used for single well, the analysis of single-layer reservoir physical properties change of injection well, can also be used for the research and the early warning analysis of advantage seepage flow passageway.
According to the scheme provided by the embodiment of the application, the injection layer information of a plurality of injection layers is obtained, because one injection layer corresponds to one injection layer information, the injection layer information comprises various information used for determining the effective permeability, the determination of the position coordinate, the position injection pressure and the injection flow of the injection layer is carried out based on the injection layer information, the effective permeability of each injection layer can be determined respectively, and the determination accuracy of the effective permeability is improved.
All the above optional technical solutions may be combined arbitrarily to form optional embodiments of the present application, and are not described herein again.
Fig. 11 is a device for determining effective permeability according to an embodiment of the present application, where the device includes:
an obtaining module 1101, configured to obtain injection layer information of multiple injection layers, where the injection layer information includes geodetic coordinate information, layer top depth information, layer bottom depth information, injection mode information, injection pressure information, and injection amount information;
a first determining module 1102, configured to determine a horizon coordinate according to the geodetic coordinate information, the top-of-layer depth information, and the bottom-of-layer depth information;
a second determining module 1103, configured to determine a horizon injection pressure according to the horizon coordinate, the injection manner information, the injection pressure information, the top of layer depth information, the bottom of layer depth information, the injection amount information, and a static pressure;
a third determining module 1104, configured to determine an injection flow rate of the injection layer according to the injection amount information;
a fourth determination module 1105 operable to determine effective permeabilities of the plurality of injection zones based on the zone injection pressure and the injection zone injection flow rate.
According to the scheme provided by the embodiment of the application, the injection layer information of a plurality of injection layers is obtained, because one injection layer corresponds to one injection layer information, the injection layer information comprises various information used for determining the effective permeability, the determination of the position coordinate, the position injection pressure and the injection flow of the injection layer is carried out based on the injection layer information, the effective permeability of each injection layer can be determined respectively, and the determination accuracy of the effective permeability is improved.
In one possible implementation, the apparatus further includes:
and the correction module is used for correcting the position coordinate according to the well deviation data information to obtain a corrected position coordinate if the injection layer information comprises the well deviation data information.
In one possible implementation, the second determining module 1103 includes a first determining sub-module and a second determining sub-module;
the first determining submodule is used for determining wellhead injection pressure according to the injection mode information and the injection pressure information;
the second determining submodule is used for determining the horizon injection pressure according to the wellhead injection pressure, the horizon coordinate, the horizon top depth information and the horizon bottom depth information.
In one possible implementation manner, the injection manner corresponding to the injection manner information comprises a forward injection and a backward injection, and the injection pressure information comprises oil pressure information and casing pressure information;
the first determining submodule is used for determining the oil pressure information as the wellhead injection pressure if the injection mode corresponding to the injection mode information is positive injection, and determining the casing pressure information as the wellhead injection pressure if the injection mode corresponding to the injection mode information is reverse injection.
In a possible implementation manner, the second determining submodule includes a first determining unit, a second determining unit, a third determining unit, and a fourth determining unit;
the first determining unit is used for determining the process pressure loss and the sum of the injection amount information;
the second determining unit is used for determining the water column pressure according to the layer top depth information and the layer bottom depth information;
the third determining unit is used for determining the static pressure according to the position coordinate;
and the fourth determining unit is used for determining the horizon injection pressure according to the process pressure loss, the wellhead injection pressure, the water column pressure and the static pressure.
In one possible implementation, the second determining unit is configured to determine the water column pressure according to the following formula:
PW＝(h1+h2)/200；
wherein ,PWIs the pressure of the water column, h1For the layer top depth information, h2Is the layer bottom depth information.
In a possible implementation manner, the third determining unit is configured to, for any injection layer in the plurality of injection layers, obtain the static pressure from the injection layer information of the any injection layer if the injection layer information of the any injection layer includes the static pressure; if the injection layer information of any injection layer does not include the static pressure, determining the static pressure of any injection layer according to the static pressure included in the injection layer information of the plurality of injection layers; and if the injection layer information of the plurality of injection layers does not include the static pressure, determining the static pressure of any injection layer according to the injection-production ratio information included in the injection layer information of the plurality of injection layers.
In a possible implementation, the fourth determining unit is configured to determine the horizon injection pressure according to the following formula:
PWER＝P0-hf+PW-PR；
wherein ,PWERInjecting pressure, P, into the horizon0Injecting pressure h into the well headfFor the process loss of pressure and PWIs the pressure of the water column, PRIs the static pressure.
In a possible implementation manner, the third determining module 1104 is configured to determine the injection amount information as the injection flow of the injection layer if the injection amount information is the injection amount information of the injection layer; and if the injection amount information is well injection amount information, determining the injection flow of the injection layer according to the injection amount information and relative injection amount information, wherein the relative injection amount information is used for indicating the flow lost by flowing through each injection layer.
In one possible implementation, the fourth determining module 1105 is configured to determine the effective permeability of the plurality of injection layers according to the following formula:
wherein q is the injection flow rate of the injection layer, B is the volume coefficient of the injection well, mu is the viscosity of the injection medium, and RETo supply radius, RWIs the well radius, S is the injection well skin factor, h is the injection horizon injection thickness, PRFor the static pressure, PWFRPressure is injected for that horizon.
In a possible implementation manner, the injection layer information further includes injection well number information, test date information, layer number information, layer injection strength information, belonging oilfield information, the block information, and injection medium information.
It should be noted that: the effective permeability determining apparatus provided in the above embodiments is only illustrated by dividing the functional modules when determining the effective permeability, and in practical applications, the function distribution may be completed by different functional modules according to needs, that is, the internal structure of the computer device is divided into different functional modules to complete all or part of the functions described above. In addition, the determination apparatus of effective permeability provided by the above embodiment and the determination method embodiment of effective permeability belong to the same concept, and specific implementation processes thereof are detailed in the method embodiment and are not described herein again.
Fig. 12 is a schematic structural diagram of a computer device according to an embodiment of the present application. The computer device 1200 may have a relatively large difference due to different configurations or performances, and may include one or more processors (CPUs) 1201 and one or more memories 1202, wherein at least one program code is stored in the one or more memories 1202, and the at least one program code is loaded and executed by the one or more processors 1201 to implement the methods provided by the above-mentioned method embodiments. Certainly, the computer device 1200 may further have components such as a wired or wireless network interface, a keyboard, and an input/output interface, so as to perform input and output, and the computer device 1200 may further include other components for implementing device functions, which are not described herein again.
In an exemplary embodiment, a computer readable storage medium, such as a memory including program code, executable by a processor, is also provided to perform the method of determining effective permeability in the above embodiments. For example, the computer-readable storage medium may be a Read-Only Memory (ROM), a Random Access Memory (RAM), a Compact Disc Read-Only Memory (CD-ROM), a magnetic tape, a floppy disk, an optical data storage device, and the like.
In an exemplary embodiment, a computer program product or a computer program is also provided, which comprises computer program code stored in a computer readable storage medium, which is read by a processor of a computer device from the computer readable storage medium, which is executed by the processor such that the computer device performs the method steps of the method of determining effective permeability provided in the above embodiments.
It will be understood by those skilled in the art that all or part of the steps for implementing the above embodiments may be implemented by hardware, or may be implemented by hardware associated with program code, and the program may be stored in a computer readable storage medium, where the above mentioned storage medium may be a read-only memory, a magnetic or optical disk, etc.
The above description is only exemplary of the present application and should not be taken as limiting, as any modification, equivalent replacement, or improvement made within the spirit and principle of the present application should be included in the protection scope of the present application.
Claims (10)
1. A method of determining effective permeability, the method comprising:
acquiring injection layer information of a plurality of injection layers, wherein the injection layer information comprises geodetic coordinate information, layer top depth information, layer bottom depth information, injection mode information, injection pressure information and injection quantity information;
determining a horizon coordinate according to the geodetic coordinate information, the layer top depth information and the layer bottom depth information;
determining the horizon injection pressure according to the horizon coordinate, the injection mode information, the injection pressure information, the layer top depth information, the layer bottom depth information, the injection amount information and the static pressure;
determining the injection flow of an injection layer according to the injection amount information;
and determining the effective permeability of the plurality of injection layers according to the horizon injection pressure and the injection flow of the injection layers.
2. The method of claim 1, wherein determining a horizon injection pressure from the horizon coordinates, the injection mode information, the injection pressure information, the top of layer depth information, the bottom of layer depth information, the injection quantity information, and a static pressure comprises:
determining wellhead injection pressure according to the injection mode information and the injection pressure information;
and determining the horizon injection pressure according to the wellhead injection pressure, the horizon coordinate, the horizon top depth information and the horizon bottom depth information.
3. The method of claim 2, wherein the injection manner information corresponds to an injection manner including a forward injection and a reverse injection, and the injection pressure information includes oil pressure information and casing pressure information;
the determining wellhead injection pressure according to the injection mode information and the injection pressure information comprises:
if the injection mode corresponding to the injection mode information is positive injection, determining the oil pressure information as the wellhead injection pressure;
and if the injection mode corresponding to the injection mode information is reverse injection, determining the casing pressure information as the wellhead injection pressure.
4. The method of claim 2, wherein the determining the horizon injection pressure from the wellhead injection pressure, the horizon coordinates, the top of layer depth information, and the bottom of layer depth information comprises:
determining the pressure loss of the process according to the injection amount information;
determining the pressure of the water column according to the layer top depth information and the layer bottom depth information;
determining the static pressure according to the horizon coordinate;
and determining the horizon injection pressure according to the process pressure loss, the wellhead injection pressure, the water column pressure and the static pressure.
5. The method of claim 4, wherein determining the water column pressure from the top of layer depth information and the bottom of layer depth information comprises:
determining the water column pressure according to the following formula:
PW＝(h1+h2)/200；
wherein ,PWIs the pressure of the water column, h1For the layer top depth information, h2Is the layer bottom depth information.
6. The method of claim 4, wherein the determining the horizon injection pressure from the process pressure loss and the wellhead injection pressure, the water column pressure, the static pressure comprises:
determining the horizon injection pressure according to the following formula:
PWER＝P0-hf+PW-PR；
wherein ,PWERInjecting pressure, P, into said horizon0Injecting pressure, h, into the well headfFor the process pressure loss and, PWIs the pressure of the water column, PRIs the static pressure.
7. The method of claim 1, wherein the determining the effective permeability of the plurality of injection zones as a function of the zone injection pressure and the injection zone injection flow rate comprises:
determining the effective permeability of the plurality of injection layers according to the following formula:
wherein q is the injection flow rate of the injection layer, B is the volume coefficient of the injection well, mu is the viscosity of the injection medium, and R isETo supply radius, RWIs the well radius, S is the injection well skin factor, h is the injection horizon injection thickness, PRIs said static pressure, PWERInjecting pressure into the horizon.
8. An apparatus for determining effective permeability, the apparatus comprising:
the device comprises an acquisition module, a processing module and a processing module, wherein the acquisition module is used for acquiring injection layer information of a plurality of injection layers, and the injection layer information comprises geodetic coordinate information, layer top depth information, layer bottom depth information, injection mode information, injection pressure information and injection quantity information;
the first determining module is used for determining a horizon coordinate according to the geodetic coordinate information, the layer top depth information and the layer bottom depth information;
a second determining module, configured to determine a horizon injection pressure according to the horizon coordinate, the injection manner information, the injection pressure information, the horizon top depth information, the horizon bottom depth information, the injection amount information, and a static pressure;
the third determining module is used for determining the injection flow of the injection layer according to the injection amount information;
a fourth determination module to determine effective permeabilities of the plurality of injection layers according to the horizon injection pressure and the injection layer injection flow.
9. A computer device comprising one or more processors and one or more memories having at least one program code stored therein, the program code loaded and executed by the one or more processors to perform the operations performed by the method of determining effective permeability of any one of claims 1 to 7.
10. A computer-readable storage medium having at least one program code stored therein, the program code being loaded and executed by a processor to perform the operations performed by the method for determining effective permeability according to any one of claims 1 to 7.
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