CN110735636B - Method and system for measuring and calculating equivalent boundary distance of reservoir of multi-layer commingled production well - Google Patents
Method and system for measuring and calculating equivalent boundary distance of reservoir of multi-layer commingled production well Download PDFInfo
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Abstract
The invention provides a measuring and calculating method and a measuring and calculating system for equivalent boundary distance of a multilayer commingled production reservoir, belonging to the field of oil and gas field development and comprising the following steps: acquiring an actually measured pressure value of the actually measured bottom hole pressure of the multi-layer combined production well along with the change of time; simulating a theoretical pressure value of the theoretical bottom hole pressure of the multi-layer commingled production well along with time change according to a pre-configured seepage model, wherein the seepage model is pre-configured according to the difference of the boundary distance of each reservoir of the multi-layer commingled production well; calculating the error between the actual measurement pressure value and the theoretical pressure value corresponding to the same time, and correcting the seepage model according to the error; according to the technical scheme, the difference of the boundary distances of all reservoirs of the multi-layer combined production well is fully considered, the characteristics of all reservoirs can be more accurately explained, the more accurate boundary equivalent distance is obtained, and the method has important guiding significance for implementation of single-well dynamic reserves, subsequent well pattern encryption and the like.
Description
Technical Field
The invention relates to the field of oil and gas field development, in particular to a method and a system for measuring and calculating equivalent boundary distance of a multilayer commingled production well reservoir.
Background
Due to the deposition and later-stage construction of the reservoirs, longitudinal heterogeneity exists among the physical properties of all the reservoirs of the commingled production well, and the distance of the boundaries of all the reservoirs is different. The existing commingled production well pressure analysis method considers that the boundary distances of all reservoirs of the multiple commingled production wells are the same, and does not consider the difference of the boundary distances of all layers of the commingled production wells.
In the process of implementing the invention, the inventor of the application finds that the scheme in the prior art cannot accurately express the vertical heterogeneity of the actually measured commingled gas well reservoir.
Disclosure of Invention
In order to solve or at least partially solve the technical problems, embodiments of the present invention provide a method and a system for measuring and calculating an equivalent boundary distance of a multi-layer commingled production reservoir.
The embodiment of the invention provides a method for measuring and calculating equivalent boundary distance of a multilayer commingled production well reservoir, which comprises the following steps: acquiring an actually measured pressure value of the actually measured bottom hole pressure of the multi-layer combined production well along with time change; simulating a theoretical pressure value of the theoretical bottom hole pressure of the multi-layer commingled production well along with time change according to a pre-configured seepage model, wherein the seepage model is pre-configured according to the difference of each reservoir boundary distance of the multi-layer commingled production well and is used for showing the corresponding relation between the theoretical bottom hole pressure value and each reservoir boundary distance of the multi-layer commingled production well; calculating an error between the actual measurement pressure value and the theoretical pressure value corresponding to the same time, and correcting the seepage model according to the error so as to enable the error to be within a preset error range; and calculating the equivalent boundary distance of the multi-layer commingled production well according to the corrected seepage model.
Preferably, the obtaining of the measured bottom hole pressure value of the multi-layer commingled production well as the change of the measured bottom hole pressure with time includes one or more of the following: placing a pressure detection device at a wellhead of the multi-layer commingled production well, measuring a wellhead pressure value of the multi-layer commingled production well in real time after the well is shut down, and calculating an actually measured bottom pressure value according to the wellhead pressure; placing a pressure detection device right above the multi-layer combined production well, and monitoring the bottom hole pressure value of the multi-layer combined production well in real time after closing the well; and placing a pressure detection device at the wellhead of the multi-layer commingled production well, measuring the wellhead pressure of the multi-layer commingled production well under the condition that the wellhead is kept open, and calculating the actually measured bottom hole pressure value according to the wellhead pressure.
Preferably, the pre-configuring the seepage model according to the difference of the reservoir boundary distances of the multi-layer commingled production well comprises: separating the respective reservoir boundaries by a distance rejIs configured to:
constructing the seepage model according to the configured boundary distances of the reservoirs, wherein the seepage model is represented by the following formula:
wherein r isejReservoir distance at jth layer; k is a radical ofjPermeability of the jth layer;
porosity of the jth layer; ctjThe comprehensive compression coefficient of the j layer; h isjIs the thickness of the jth layer; pjIs the pressure of the j-th layer; j is the sequence number of the commingled production well reservoir, and j is 1,2,3 … n; p is a radical ofwBottom hole pressure; q is the yield of the multi-layer combined production well; μ is the fluid viscosity; b is the fluid isothermal volume coefficient; r iswIs the wellbore radius.
Preferably, the calculating the equivalent boundary distance of the multi-layer commingled production well according to the corrected seepage model comprises: calculating the boundary distance of each reservoir of the multi-layer commingled production well according to the corrected seepage model and the theoretical pressure value; and calculating the equivalent distance of the reservoir boundary of the commingled production well by using the equivalent seepage volume according to the boundary distance of each reservoir.
Correspondingly, the embodiment of the invention provides a system for measuring and calculating the equivalent boundary distance of a multilayer commingled production well reservoir, which comprises the following steps: the acquisition module is used for acquiring an actually measured pressure value of the actually measured bottom hole pressure of the multi-layer combined production well along with time change; the simulation module is used for simulating a theoretical pressure value of the theoretical bottom hole pressure of the multi-layer commingled production well along with time change according to a pre-configured seepage model, wherein the seepage model is pre-configured according to the difference of each reservoir boundary distance of the multi-layer commingled production well and used for showing the corresponding relation between the theoretical bottom hole pressure and each reservoir boundary distance of the multi-layer commingled production well; the correction module is used for calculating the error between the actual measurement pressure value and the theoretical pressure value corresponding to the same time, and correcting the constructed seepage model according to the error so as to enable the error to be within a preset error range; and the measuring and calculating module is used for measuring and calculating the equivalent boundary distance of the multi-layer commingled production well according to the corrected seepage model.
Preferably, the obtaining module includes a pressure detecting device, and the pressure detecting device obtains a measured pressure value of the measured bottom hole pressure changing with time by using one or more of the following: placing a pressure detection device at a wellhead of the multi-layer commingled production well, obtaining a wellhead pressure value of the multi-layer commingled production well measured after closing the well in real time, and calculating the actually measured bottom pressure value according to the wellhead pressure; placing a pressure detection device right above the multi-layer combined production well, and measuring the bottom hole pressure value of the multi-layer combined production well after closing the well in real time; and placing a pressure detection device at the wellhead of the multi-layer commingled production well, acquiring the wellhead pressure value of the multi-layer commingled production well measured under the condition of keeping the wellhead open in real time, and calculating the actually measured bottom hole pressure value according to the wellhead pressure.
Preferably, the pressure detecting device is a pressure gauge.
Preferably, the simulation module includes: a configuration submodule for configuring said respective reservoir boundary distances rejIs configured to:
and the modeling submodule is used for constructing the seepage model shown as the following formula according to the configured boundary distance of each reservoir:
wherein r isejReservoir distance at jth layer; k is a radical ofjPermeability of the jth layer;
porosity of the jth layer; ctjThe comprehensive compression coefficient of the j layer; h isjIs the thickness of the jth layer; pjIs the pressure of the j-th layer; j is the sequence number of the commingled production well reservoir, and j is 1,2,3 … n; p is a radical ofwBottom hole pressure; q is the production of a multi-layer commingled production wellAn amount; μ is the fluid viscosity; b is the fluid isothermal volume coefficient; r iswIs the wellbore radius.
Preferably, the estimation module comprises: the layered measuring and calculating submodule is used for measuring and calculating the boundary distance of each reservoir of the multi-layer combined production well according to the corrected seepage model and the theoretical pressure value; and the equivalent measuring and calculating submodule is used for measuring and calculating the equivalent distance of the reservoir boundary of the commingled production well by using the equivalent seepage volume according to the boundary distance of each reservoir.
Accordingly, the embodiment of the present invention further provides a machine-readable storage medium, where the machine-readable storage medium has instructions stored thereon, and the instructions are used for causing a machine to perform the method for calculating the equivalent boundary distance of the multi-layer commingled production reservoir described above in this application.
Through the technical scheme, the seepage model is preconfigured according to the difference of the boundary distances of all reservoirs of the multi-layer commingled production well, the actual boundary distances of all the reservoirs are fully considered, so that the equivalent boundary distances of the multi-layer commingled production well are obtained through model construction, analysis and measurement.
Additional features and advantages of embodiments of the invention will be set forth in the detailed description which follows.
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The accompanying drawings, which are included to provide a further understanding of the embodiments of the invention and are incorporated in and constitute a part of this specification, illustrate embodiments of the invention and together with the description serve to explain the embodiments of the invention without limiting the embodiments of the invention. In the drawings:
FIG. 1 is a flow chart of a method for measuring and calculating equivalent boundary distances of a multi-layer commingled production well reservoir provided by an embodiment of the invention;
FIG. 2 is a schematic diagram of a physical model of a multi-layer commingled production well seepage model provided by an embodiment of the invention;
FIG. 3 is a schematic diagram illustrating an error value between a measured pressure value and a theoretical pressure value corresponding to the same time according to an embodiment of the present invention;
FIG. 4 is a schematic diagram of an equivalent seepage principle provided by an embodiment of the present invention;
FIG. 5 is a flowchart of an application example of the method for measuring and calculating the equivalent boundary distance of the multi-layer commingled production well reservoir provided by the embodiment of the invention;
FIG. 6 is a block diagram of a system for measuring and calculating equivalent boundary distances of a multi-layer commingled production well reservoir provided by an embodiment of the invention;
FIG. 7 is a block diagram of a simulation module provided by an embodiment of the present invention; and
fig. 8 is a block diagram of a measurement and calculation module according to an embodiment of the present invention.
Description of the reference numerals
1. Acquisition module 2 and simulation module
3. Correction module 4 and measuring and calculating module
21. Configuration submodule 22 and modeling submodule
41. Layered measurement and calculation submodule 42 and equivalent measurement and calculation submodule
Detailed Description
The following detailed description of embodiments of the invention refers to the accompanying drawings. It should be understood that the detailed description and specific examples, while indicating embodiments of the invention, are given by way of illustration and explanation only, not limitation.
Fig. 1 is a flowchart of a method for calculating an equivalent boundary distance of a multi-layer commingled production well reservoir according to an embodiment of the present invention, and as shown in fig. 1, the method may include:
s100, obtaining an actually measured pressure value of the actually measured bottom hole pressure of the multi-layer combined production well along with time change.
In the embodiment of the invention, the measured pressure value of the measured bottom hole pressure of the multi-layer combined production well along with the change of time is obtained by adopting one or more of the following modes:
1. and placing the pressure detection device at the wellhead of the multi-layer commingled production well, measuring the wellhead pressure value of the multi-layer commingled production well in real time after the well is closed, and calculating the actually measured bottom pressure value according to the wellhead pressure.
In particular, for some high pressure gas wells, it is sometimes difficult to operate the lower pressure gauge. If the underground pressure gauge is forcibly closed, the sealing on the blowout prevention pipe is easy to be punctured due to high wellhead pressure, the gas amount is too large during production, the pressure gauge cannot be arranged below the blowout prevention pipe, and even various accidents are caused. In view of these circumstances, in addition to the fact that the downhole accumulation must be measured by a pressure gauge, for a dry gas well, the formation pressure and the bottom hole pressure can be calculated according to wellhead pressure measurement data.
For example, a pressure gauge is placed at a wellhead, wellhead pressure is obtained through real-time measurement after shut-in, bottom hole pressure is converted according to the wellhead pressure, and subsequent fitting calculation is performed after the wellhead pressure is converted into the bottom hole pressure by considering wellbore abrasion resistance and liquid level height when the wellhead pressure is converted into the bottom hole pressure.
For example: the wellhead pressure measured by the pressure gauge is PhThen bottom hole pressure Pw＝Ph+ ρ gh, where ρ represents the wellbore gas density; g represents the gravitational acceleration; h represents the bottom hole depth.
2. And (3) placing the pressure detection device right above the multi-layer combined production well, and monitoring the bottom hole pressure value of the multi-layer combined production well in real time after closing the well.
In the embodiment of the invention, the most direct method for measuring the bottom hole pressure is to place a pressure gauge at the bottom of the well, and monitor the bottom hole pressure value of the multi-layer commingled production well in real time after the well is shut down.
For example, a pressure gauge can be put right above a commingled production layer of a multi-layer commingled production well, and the bottom hole pressure change value after the well is shut down is monitored in real time.
3. And placing the pressure detection device at the wellhead of the multi-layer commingled production well, measuring the wellhead pressure of the multi-layer commingled production well under the condition of keeping the wellhead open, and calculating the actually measured bottom hole pressure value according to the wellhead pressure.
Specifically, a pressure gauge may be placed at the wellhead of the multi-layer commingled production well, and the wellhead pressure change value may be measured while keeping the wellhead open, and converted to the bottom hole pressure.
In the embodiment of the present invention, one of the above methods for measuring the bottom hole pressure value is usually selected, and in practical applications, one of the methods may be selected according to needs, or other suitable methods for measuring the bottom hole pressure may also be selected, and two or more methods may also be selected to measure the bottom hole pressure respectively, and a weighted average value calculation or the like is performed on the measured bottom hole pressure values, so as to improve the accuracy of the bottom hole pressure measurement.
S200, simulating theoretical pressure values of theoretical bottom hole pressure of the multi-layer commingled production well along with time change according to a pre-configured seepage model, wherein the seepage model is pre-configured according to differences of all reservoir boundary distances of the multi-layer commingled production well and used for showing corresponding relations between the theoretical bottom hole pressure values and all reservoir boundary distances of the multi-layer commingled production well.
Fig. 2 is a schematic diagram of a physical model of a multi-layer commingled production well seepage model provided by an embodiment of the present invention, and as shown in fig. 2, reservoir boundary distances of each commingled production layer of a multi-layer commingled production well are different, and the reservoir boundary distances r are determined according to the reservoir boundary distancesejIs configured to:
according to the configured boundary distances of the reservoirs, a mathematical model corresponding to a physical model of the seepage model is constructed (without considering the reservoirs and the skin) as shown in the following formula (1):
wherein p iswBottom hole pressure in MPa; q is the well production in m3D; μ is the fluid viscosity in mPa · s; b is the fluid isothermal volume coefficient, unit m3/m3；rwIs the wellbore radius in m; r isejReservoir distance at stratum j, in m; k is a radical ofjPermeability of the j-th layer, unit 10-3μm2；
Porosity of the jth layer in unit%; ctjIs the integrated compression coefficient of the j layer in MPa-1；hjIs the thickness of the jth layer, in m; pjIs the pressure of the j-th layer in MPa; j is the sequence number of the commingled well reservoir, and j is 1,2,3 … n.
After the Laplace transform is carried out on the formula (1), a dimensionless mathematical model (without considering well storage and skin) in a pull-type space is obtained as follows:
wherein: coefficient of flow
Dimensionless; storage capacity factor
Dimensionless; dimensionless time
Dimensionless; dimensionless pressure
Dimensionless; dimensionless distance
Dimensionless; u is a pull-type space variable and is dimensionless.
Solving equation (2) to obtain a dimensionless bottom hole pressure solution without considering well reservoir and skin
In formula (3):
dimensionless; i is0The first modified Bessel function is 0 order and has no dimension; k0Is a modified Bessel function of the second class 0, dimensionless, A1And B1Is the unknown to be solved. To A1And B1And setting a reasonable initial value, and calculating the theoretical bottom hole pressure value of the multi-layer commingled production well by using the set initial value.
The method comprises the steps of obtaining a dimensionless bottom hole pressure solution considering well storage and skin coefficients in a pull-type space by using a Du-Ha's principle and considering the influences of the well storage effect and the skin effect on the bottom hole pressure, and obtaining the dimensionless bottom hole pressure solution in a real number space by using a Stehfest numerical inversion method, thereby obtaining a theoretical pressure value of the theoretical bottom hole pressure of the multi-layer combined production well along with the change of time.
Specifically, on the basis of obtaining a bottom-hole pressure solution through calculation according to the seepage model, the influence of a shaft reservoir effect and a skin effect on the bottom-hole pressure is considered according to the Du-Hammet principle. For example: the whole multi-layer commingled production well system is divided into three parts, namely a shaft, a reservoir and a boundary: the well bore part considers the well bore storage effect when closing the well and is characterized by a well storage coefficient; the pressure drop loss from the shaft to the reservoir is characterized by a skin coefficient; reservoir to boundary commingled production well reservoir flow is characterized using the seepage model described above. Therefore, a more accurate theoretical pressure value of the theoretical bottom hole pressure of the multi-layer combined production well changing along with time is obtained.
S300, calculating an error between the actual measurement pressure value and the theoretical pressure value corresponding to the same time, and correcting the seepage model according to the error so that the error is within a preset error range.
In the embodiment of the present invention, based on the measured pressure value of the measured bottom-hole pressure of the multi-layer commingled production well varying with time in step S100 and the theoretical pressure value of the theoretical bottom-hole pressure of the multi-layer commingled production well varying with time simulated in step S200, an error between the measured pressure value and the theoretical pressure value corresponding to the same time is calculated by using a least square method (or other applicable neural network algorithm may be used, which is not limited by the present invention), and the error is calculated according to the calculated errorFor the error to, for the set A1And B1The initial value of the multi-layer commingled production well is adjusted to correct the seepage model of the multi-layer commingled production well.
Specifically, reservoir basic physical parameters (such as the number of reservoir layers of a multi-layer co-production well, the thickness of each reservoir, the porosity, the comprehensive compressibility, the original formation pressure and the like) and initial fitting parameter values (set A) are given according to known reservoir information1And B1The initial values of (a) include: well storage coefficients, skin coefficients, permeability of each layer, boundary distance of each layer and the like of a multi-layer commingled production well) to obtain bottom hole pressure calculation results of the seepage model of the invention corresponding to the parameters; setting a preset error value, and calculating the error value between the bottom hole pressure and the actually measured bottom hole pressure of the seepage model by using a least square method; if the error between the two is less than or equal to the preset error value, outputting a fitting parameter result; otherwise, adjust the fitting parameters (A)1And B1) And recalculating the bottom hole pressure and judging the error value until the error value is less than or equal to the preset error value, stopping the repeated calculation and outputting a fitting parameter value.
In addition, A is1And B1Not a single physical or mathematical parameter in the conventional sense, but a parameter matrix consisting of a plurality of parameters, for example: the method can comprise parameters such as well storage coefficients, skin coefficients, permeability of each layer, boundary distance of each layer and the like of the multi-layer commingled production well, and the adjustment of any one of the parameters in the matrix can influence A1And B1The value of (c). For set A1And B1The process of adjusting the initial value of (2) is a process of adjusting a plurality of parameters in the parameter matrix.
For example, fig. 3 is a schematic diagram of an error value between a measured pressure value and a theoretical pressure value corresponding to the same time according to the embodiment of the present invention, and as shown in fig. 3, the measured pressure value and the theoretical pressure value are fitted, and the fitting process substantially calculates an error between the measured pressure value and the theoretical pressure value corresponding to the same time, and adjusts the parameter matrix a according to the error1And B1Parameters included to make the error at a predetermined errorDifference range, and hence the seepage model. The measured pressure values correspond to the pressures (test data) in FIG. 3, the theoretical pressure values correspond to the pressures (theoretical data) in FIG. 3, and the values are adjusted according to A1And B1When the fitting result of the theoretical pressure value calculated by the corrected seepage model and the actually measured pressure value obtained by actual measurement can achieve the fitting effect as shown in fig. 3, it indicates that a1And B1The setting is reasonable.
And S400, calculating the equivalent boundary distance of the multi-layer commingled production well according to the corrected seepage model.
In the embodiment of the invention, the boundary distance of each reservoir of the multi-layer commingled production well is measured and calculated according to the corrected seepage model and the theoretical pressure value; and calculating the equivalent distance of the reservoir boundary of the commingled production well by using the equivalent seepage volume according to the boundary distance of each reservoir.
Specifically, taking the schematic diagram of the equivalent Seepage principle provided by the embodiment of the present invention shown in fig. 4 as an example, the equivalent Seepage volume esv (equivalent drainage volume) is defined according to the equal volume principle: one complex percolation volume (as shown in fig. 4 a) may be replaced with the simplest percolation volume (as shown in fig. 4 b). And because the equivalent seepage volume is not unique, at least one simple ESV can be found out from a complex seepage volume, so that the actual reservoir of the multi-layer commingled production well can be reasonably explained by using various well testing models under the condition of not considering geological data of the multi-layer commingled production well. According to the ESV concept, the equivalent boundary distance of the multi-layer commingled production well with the multiple reservoir boundary distance differences can be calculated according to the following formula (4):
wherein r isMRepresenting the equivalent distance of the boundary of the multi-layer commingled production well; r isjRepresenting the reservoir distance at the jth layer; h isjRepresents the thickness of the j-th layer; phi is ajIndicating the porosity of the j layer; k is a radical ofjRepresents the permeability of the j-th layer; j represents the sequence number of the commingled producing well reservoir, j is 1,2,3 … n; h istIndicating the current timeThe thickness of a reservoir corresponding to bottom hole pressure is carved;
representing the average value of the porosity of each reservoir of the multi-layer commingled production well;
the average value of the permeability of each reservoir of the multi-layer commingled production well is shown.
And (4) obtaining the parameters of each co-production layer of the multi-layer co-production well in the formula (4) according to the fitting result of the constructed mathematical model of the seepage model to bottom hole pressure data.
And according to the equivalent seepage volume principle, calculating the equivalent distance of the reservoir boundary according to the basic physical parameters (such as the number of layers, the thickness of each layer, the porosity and the comprehensive compressibility) of each reservoir of the multi-layer combined production well and the final fitting parameters (including but not limited to the permeability of each layer and the boundary distance of each layer).
The method for calculating the equivalent boundary distance of the multi-layer commingled production well reservoir provided by the embodiment of the invention is illustrated by specific application examples.
Fig. 5 is a flowchart of an application example of the method for measuring and calculating the equivalent boundary distance of the multi-layer commingled production well reservoir according to the embodiment of the present invention, and as shown in fig. 5, the method may include the following steps:
s11, actually measuring the bottom hole pressure in various ways.
Specifically, the bottom hole pressure after the well is shut down is directly measured by a pressure gauge, or the bottom hole pressure is measured and converted into the bottom hole pressure to obtain the bottom hole pressure measured value. To plot a measured bottom hole pressure value curve.
S12, drawing an actually measured bottom hole pressure value curve Pt0＝f(t)。
Drawing an actually measured bottom hole pressure value curve P according to the bottom hole pressure actually measured in the step S11t0＝f(t)。
S21, inputting initial fitting parameters M0(C0，S0，kj0，rej0) The number of reservoir layers of the multi-layer commingled production well and the original earth pressurepjThickness of each reservoir hjPorosity, degree of porosity
CtjIs the integrated compression factor of the j-th layer.
Specifically, in a seepage model constructed in advance, initial fitting parameters are input to calculate a theoretical bottom hole pressure value, so that a theoretical bottom hole pressure value curve is drawn.
S22, calculating a theoretical bottom hole pressure value curve P according to the seepage modelt＝F(M0,t)。
Drawing a theoretical bottom hole pressure value curve P according to the theoretical bottom hole pressure value obtained in the step S11t＝F(M0,t)。
And S3, fitting the actual bottom hole pressure value curve and the theoretical bottom hole pressure value curve.
And fitting the actual bottom hole pressure value curve obtained in the step S12 and the theoretical bottom hole pressure value curve obtained in the step S22.
S4, determining the fitting result between the actual bottom hole pressure value and the theoretical bottom hole pressure value in step S3, for example: judging whether the error between the actual bottom hole pressure value and the theoretical bottom hole pressure value meets the preset error requirement or not: | pt-pt0|<e, wherein e is a preset error value. If yes, go to step S42 directly; if not, go to step S41.
S41, fitting the parameter M, and re-assigning the value to M0。
If the fitting result in step S4 does not satisfy the preset error requirement, it indicates that the fitting parameter M is not reasonable and needs to be reassigned to M0And returns to execution of step S21.
S42, outputting fitting parameters M (C, S, k)j，rej)。
If the fitting result in step S4 satisfies the preset error requirement, it indicates that the fitting parameter M is reasonable, and at this time, the fitting parameter M (C, S, k) is outputj，rej) And (4) finishing.
S5, according to ESV and rejAnd calculating the equivalent boundary distance of the multi-layer commingled production well.
Determining a seepage model according to the fitting parameters obtained in the step S42, thereby determining the boundary distance r of each layer of the multi-layer co-production layerejAnd calculating the equivalent boundary distance of the multi-layer commingled production well by using the equivalent seepage volume ESV.
Fig. 6 is a block diagram of a system for measuring and calculating an equivalent boundary distance of a multi-layer commingled production reservoir according to an embodiment of the present invention, and as shown in fig. 6, the system for measuring and calculating an equivalent boundary distance of a multi-layer commingled production reservoir includes: the system comprises an acquisition module 1, a data processing module and a data processing module, wherein the acquisition module is used for acquiring an actually measured pressure value of actually measured bottom hole pressure of a multi-layer combined production well along with time change; the simulation module 2 is used for simulating theoretical pressure values of theoretical bottom hole pressure of the multi-layer commingled production well changing along with time according to a pre-configured seepage model, wherein the seepage model is pre-configured according to differences of all reservoir boundary distances of the multi-layer commingled production well and used for showing a corresponding relation between the theoretical bottom hole pressure and all reservoir boundary distances of the multi-layer commingled production well; the correction module 3 is used for calculating an error between an actual measurement pressure value and a theoretical pressure value corresponding to the same time, and correcting the constructed seepage model according to the error so as to enable the error to be within a preset error range; and the measuring and calculating module 4 is used for measuring and calculating the equivalent boundary distance of the multi-layer combined production well according to the corrected seepage model.
The acquisition module 1 comprises a pressure detection device (not shown in the figures) and the pressure detection device acquires a measured pressure value of the measured bottom hole pressure over time using one or more of the following: placing a pressure detection device at the wellhead of the multi-layer commingled production well, obtaining the wellhead pressure value of the multi-layer commingled production well measured after closing the well in real time, and calculating the actually measured bottom pressure value according to the wellhead pressure; placing a pressure detection device right above the multi-layer combined production well, and measuring the bottom hole pressure value of the multi-layer combined production well after closing the well in real time; and placing the pressure detection device at the wellhead of the multi-layer commingled production well, acquiring the wellhead pressure value of the multi-layer commingled production well measured under the condition of keeping the wellhead open in real time, and calculating the actually measured bottom pressure value according to the wellhead pressure.
Preferably, the pressure detecting means is a pressure gauge.
FIG. 7 is a block diagram of an embodiment of the present inventionBlock diagram of a simulation module, as shown in fig. 7, the simulation module 2 includes: a configuration submodule 21 for assigning respective reservoir boundary distances rejIs configured to:
and a modeling submodule 22 for constructing a seepage model shown in the above formula (1) according to the configured boundary distances of the reservoirs.
Fig. 8 is a block diagram of a measurement and calculation module according to an embodiment of the present invention, and as shown in fig. 8, the measurement and calculation module 4 includes: the layered measuring and calculating submodule 41 is used for measuring and calculating the boundary distance of each reservoir of the multi-layer combined production well according to the corrected seepage model and the theoretical pressure value; and the equivalent measuring and calculating submodule 42 is used for measuring and calculating the equivalent distance of the reservoir boundary of the commingled production well by utilizing the equivalent seepage volume according to the boundary distance of each reservoir.
For other specific implementation details and beneficial effects of the system for measuring and calculating the equivalent boundary distance of the multi-layer commingled production well reservoir, reference is made to the method for measuring and calculating the equivalent boundary distance of the multi-layer commingled production well reservoir, and details are not repeated here.
Through the technical scheme, the seepage model is preconfigured according to the difference of the boundary distances of all reservoirs of the multi-layer commingled production well, the actual boundary distances of all the reservoirs are fully considered, so that the equivalent boundary distances of the multi-layer commingled production well are obtained through model construction, analysis and measurement.
The device for measuring and calculating the equivalent boundary distance of the multi-layer commingled production well reservoir comprises a processor and a memory, wherein the acquisition module, the simulation module, the correction module and the like are stored in the memory as program units, and the processor executes the program units stored in the memory to realize corresponding functions.
The processor comprises a kernel, and the kernel calls the corresponding program unit from the memory. One or more than one kernel can be set, and the equivalent boundary distance of the multi-layer commingled production well reservoir can be measured and calculated by adjusting the kernel parameters.
The memory may include volatile memory in a computer readable medium, Random Access Memory (RAM) and/or nonvolatile memory such as Read Only Memory (ROM) or flash memory (flash RAM), and the memory includes at least one memory chip.
The embodiment of the invention provides a storage medium, wherein a program is stored on the storage medium, and when the program is executed by a processor, the method for measuring and calculating the equivalent boundary distance of the multilayer commingled production well reservoir is realized.
The embodiment of the invention provides a processor, which is used for running a program, wherein the method for measuring and calculating the equivalent boundary distance of the multi-layer commingled production well reservoir is executed when the program runs.
As will be appreciated by one skilled in the art, embodiments of the present application may be provided as a method, system, or computer program product. Accordingly, the present application may take the form of an entirely hardware embodiment, an entirely software embodiment or an embodiment combining software and hardware aspects. Furthermore, the present application may take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, and the like) having computer-usable program code embodied therein.
The present application is described with reference to flowchart illustrations and/or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of the application. It will be understood that each flow and/or block of the flow diagrams and/or block diagrams, and combinations of flows and/or blocks in the flow diagrams and/or block diagrams, can be implemented by computer program instructions. These computer program instructions may be provided to a processor of a general purpose computer, special purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, create means for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be stored in a computer-readable memory that can direct a computer or other programmable data processing apparatus to function in a particular manner, such that the instructions stored in the computer-readable memory produce an article of manufacture including instruction means which implement the function specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer implemented process such that the instructions which execute on the computer or other programmable apparatus provide steps for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
In a typical configuration, a computing device includes one or more processors (CPUs), input/output interfaces, network interfaces, and memory.
The memory may include forms of volatile memory in a computer readable medium, Random Access Memory (RAM) and/or non-volatile memory, such as Read Only Memory (ROM) or flash memory (flash RAM). The memory is an example of a computer-readable medium.
Computer-readable media, including both non-transitory and non-transitory, removable and non-removable media, may implement information storage by any method or technology. The information may be computer readable instructions, data structures, modules of a program, or other data. Examples of computer storage media include, but are not limited to, phase change memory (PRAM), Static Random Access Memory (SRAM), Dynamic Random Access Memory (DRAM), other types of Random Access Memory (RAM), Read Only Memory (ROM), Electrically Erasable Programmable Read Only Memory (EEPROM), flash memory or other memory technology, compact disc read only memory (CD-ROM), Digital Versatile Discs (DVD) or other optical storage, magnetic cassettes, magnetic tape magnetic disk storage or other magnetic storage devices, or any other non-transmission medium that can be used to store information that can be accessed by a computing device. As defined herein, a computer readable medium does not include a transitory computer readable medium such as a modulated data signal and a carrier wave.
It should also be noted that the terms "comprises," "comprising," or any other variation thereof, are intended to cover a non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements does not include only those elements but may include other elements not expressly listed or inherent to such process, method, article, or apparatus. Without further limitation, an element defined by the phrase "comprising an … …" does not exclude the presence of other identical elements in the process, method, article, or apparatus that comprises the element.
The above are merely examples of the present application and are not intended to limit the present application. Various modifications and changes may occur to those skilled in the art. Any modification, equivalent replacement, improvement, etc. made within the spirit and principle of the present application should be included in the scope of the claims of the present application.
Claims (10)
1. A method for measuring and calculating the equivalent boundary distance of a multilayer commingled production well reservoir is characterized by comprising the following steps of:
acquiring an actually measured pressure value of the actually measured bottom hole pressure of the multi-layer combined production well along with time change;
simulating a theoretical pressure value of the theoretical bottom hole pressure of the multi-layer commingled production well along with time change according to a pre-configured seepage model, wherein the seepage model is pre-configured according to the difference of each reservoir boundary distance of the multi-layer commingled production well and is used for showing the corresponding relation between the theoretical pressure value and each reservoir boundary distance of the multi-layer commingled production well;
calculating an error between the actual measurement pressure value and the theoretical pressure value corresponding to the same time, and correcting the seepage model according to the error so as to enable the error to be within a preset error range; and
and calculating the equivalent boundary distance of the multi-layer commingled production well according to the corrected seepage model.
2. The method for measuring and calculating the equivalent boundary distance of the multi-layer commingled production well reservoir according to claim 1, wherein the obtaining of the measured pressure value of the measured bottom hole pressure of the multi-layer commingled production well, which varies with time, comprises one or more of the following:
placing a pressure detection device at a wellhead of the multi-layer commingled production well, measuring a wellhead pressure value of the multi-layer commingled production well in real time after the well is shut down, and calculating the actually measured pressure value according to the wellhead pressure;
placing a pressure detection device right above the multi-layer combined production well, and monitoring the bottom hole pressure value of the multi-layer combined production well in real time after closing the well; and
and placing a pressure detection device at the wellhead of the multi-layer commingled production well, measuring the wellhead pressure of the multi-layer commingled production well under the condition of keeping the wellhead open, and calculating the actual measurement pressure value according to the wellhead pressure.
3. The method for calculating reservoir equivalent boundary distances of a multi-layer commingled production well according to claim 1, wherein the pre-configuring of the seepage model according to the differences of the reservoir boundary distances of the multi-layer commingled production well comprises:
separating the respective reservoir boundaries by a distance rejIs configured to:
constructing the seepage model according to the configured boundary distances of the reservoirs, wherein the seepage model is represented by the following formula:
wherein r isejReservoir distance at jth layer; k is a radical ofjPermeability of the jth layer;
porosity of the jth layer; ctjThe comprehensive compression coefficient of the j layer; h isjIs the thickness of the jth layer; pjIs the pressure of the j-th layer; j is the sequence number of the commingled production well reservoir, and j is 1,2,3 … n; p is a radical ofwBottom hole pressure; q is the yield of the multi-layer combined production well; μ is the fluid viscosity; b is the fluid isothermal volume coefficient; r iswIs the wellbore radius.
4. The method for calculating the equivalent boundary distance of the multi-layer commingled production well reservoir according to the claim 1, wherein the calculating the equivalent boundary distance of the multi-layer commingled production well according to the corrected seepage flow model comprises:
calculating the boundary distance of each reservoir of the multi-layer commingled production well according to the corrected seepage model and the theoretical pressure value; and
and calculating the equivalent distance of the reservoir boundary of the commingled production well by using the equivalent seepage volume according to the boundary distance of each reservoir.
5. A machine-readable storage medium having instructions stored thereon for causing a machine to perform the method of multilaminate well reservoir equivalent perimeter estimation of any of claims 1-4.
6. A system for measuring and calculating the equivalent boundary distance of a multi-layer commingled production well reservoir is characterized by comprising the following steps:
the acquisition module is used for acquiring an actually measured pressure value of the actually measured bottom hole pressure of the multi-layer combined production well along with time change;
the simulation module is used for simulating a theoretical pressure value of the theoretical bottom hole pressure of the multi-layer commingled production well along with time change according to a pre-configured seepage model, wherein the seepage model is pre-configured according to the difference of each reservoir boundary distance of the multi-layer commingled production well and used for showing the corresponding relation between the theoretical bottom hole pressure and each reservoir boundary distance of the multi-layer commingled production well;
the correction module is used for calculating the error between the actual measurement pressure value and the theoretical pressure value corresponding to the same time, and correcting the constructed seepage model according to the error so as to enable the error to be within a preset error range; and
and the measuring and calculating module is used for measuring and calculating the equivalent boundary distance of the multi-layer combined production well according to the corrected seepage model.
7. The system for measuring and calculating the equivalent boundary distance of a multi-layer commingled production reservoir of claim 6, wherein the obtaining module comprises a pressure detecting device, and the pressure detecting device obtains a measured pressure value of the measured bottom hole pressure along with time by using one or more of the following:
placing a pressure detection device at a wellhead of the multi-layer commingled production well, obtaining a wellhead pressure value of the multi-layer commingled production well measured after closing the well in real time, and calculating the actual measurement pressure value according to the wellhead pressure;
placing a pressure detection device right above the multi-layer combined production well, and measuring the bottom hole pressure value of the multi-layer combined production well after closing the well in real time; and
and arranging a pressure detection device at a wellhead of the multi-layer commingled production well, acquiring a wellhead pressure value of the multi-layer commingled production well measured under the condition of keeping the wellhead open in real time, and calculating the actual measurement pressure value according to the wellhead pressure.
8. The system for calculating the equivalent boundary distance of a multi-layer commingled production reservoir of claim 7, wherein the pressure detection device is a pressure gauge.
9. The system for calculating equivalent boundary distances of a multi-layer commingled production reservoir of claim 6, wherein the simulation module comprises:
a configuration submodule for configuring said respective reservoir boundary distances rejIs configured to:
and
the modeling submodule is used for constructing the seepage model shown as the following formula according to the configured boundary distance of each reservoir:
wherein r isejReservoir distance at jth layer; k is a radical ofjPermeability of the jth layer;
porosity of the jth layer; ctjThe comprehensive compression coefficient of the j layer; h isjIs the thickness of the jth layer; pjIs the pressure of the j-th layer; j is the sequence number of the commingled production well reservoir, and j is 1,2,3 … n; p is a radical ofwBottom hole pressure; q is the yield of the multi-layer combined production well; μ is the fluid viscosity; b is the fluid isothermal volume coefficient; r iswIs the wellbore radius.
10. The system for calculating equivalent boundary distances of a multi-layer commingled production reservoir of claim 6, wherein the calculation module comprises:
the layered measuring and calculating submodule is used for measuring and calculating the boundary distance of each reservoir of the multi-layer combined production well according to the corrected seepage model and the theoretical pressure value; and
and the equivalent measuring and calculating submodule is used for measuring and calculating the equivalent distance of the reservoir boundary of the commingled production well by using the equivalent seepage volume according to the boundary distance of each reservoir.
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