CN108798654A - Method and device for determining corresponding relation between bottom hole pressure and time of shale gas well - Google Patents
Method and device for determining corresponding relation between bottom hole pressure and time of shale gas well Download PDFInfo
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Abstract
The embodiment of the application discloses a method and a device for determining the corresponding relation between the bottom hole pressure and the time of a shale gas well. The method comprises the following steps: determining a first incidence relation between a second fracture permeability and bottom hole pressure corresponding to the target gas well based on the rock mechanics data and the first fracture permeability; wherein the second fracture permeability is used to characterize the fracture permeability of the reservoir of interest at the bottom hole pressure; determining a second incidence relation between the yield of the target gas well and the bottom hole pressure, the first fracture permeability and the production time of the target gas well based on the formation permeability, the formation porosity, the formation thickness and the fracture attribute data; and determining the corresponding relation between the bottom hole pressure corresponding to the target gas well and the production time according to the first correlation and the second correlation. According to the technical scheme provided by the embodiment of the application, the final recoverable reserves of the shale gas well can be improved.
Description
Technical field
This application involves construction of natural gas fields technical fields, more particularly to determine pair of the bottom pressure and time of shale gas well
The method and device that should be related to.
Background technology
As how deepening continuously for shale gas Exploitation degree leads in the case of drilling well and gradually ripe fracturing technique
Crossing gas well, efficiently management has become one of the key problem that major Gas Company is concerned about to obtain higher development benefit.Gas
The bottom pressure of well and the correspondence of time, commonly referred to as gas well liquid loading system, also referred to as working system are the daily lifes of gas well
Important means in production management, rational production system can either ensure to maintain higher gas well deliverability again can to obtain higher
Income at a specified future date, analog result show that gas well ultimate cumulative recovery often improves 20% and can improve 4% internal rate of return (IRR).
Horizontal well drilling and the technical way that volume fracturing is shale gas exploitation.What shale reservoir formd after pressure answers
Miscellaneous fracture network, these complex fracture networks obtain higher flow conductivity by being pumped into a large amount of proppant, with lamelliform
Shale reservoir together constitute " artificial gas reservoir " with multiple dimensioned seepage flow space.During gas well liquid loading, gas is continuous
The caused strata pressure failure of extraction makes effective stress gradually increase, and proppant is squeezed in seepage flow space, occurs not
Phenomena such as with the insertion of degree, crushing, dissolving.The special laminar reservior structure of shale is but also flow channel is easier to send out simultaneously
Change shape, and flow channel penetrating power is caused to significantly reduce.Therefore, how to alleviate the reduction of " artificial gas reservoir " percolation ability becomes
Outstanding problem in shale gas well development management work.
The optimal of shale gas well matches the scientific and reasonable technical support of production scheme long-term lacking at present, can only borrow " initial stage use
Several with production, semiempirical pressure control scheme of the control annual decline rate 40~50% " after going into operation 1~1.5 year of several points of open-flow capacity, this
Kind scheme needs enough Production development data supportings and complicated analysis and summary, lacks development theories support, and be only applicable in
In the similar block of Geological Engineering background, do not have application value.There is an urgent need for a set of scientific and reasonable for the Efficient Development of shale gas
Gas well liquid loading system optimization method, to improve the ultimate recoverable reserves of shale gas well.
Invention content
The purpose of the embodiment of the present application is to provide the method for the bottom pressure and the correspondence of time of determining shale gas well
And device, to improve the ultimate recoverable reserves of shale gas well.
In order to solve the above technical problems, the embodiment of the present application, which provides, determines that the bottom pressure of shale gas well is corresponding with the time
What the method and device of relationship was realized in：
The method for determining the bottom pressure of shale gas well and the correspondence of time provides purpose reservoir in purposeful work area
Layer attribute data, crack attribute data and rock mechanics data；Wherein, the purpose work area includes boring to meet the purpose
The target gas well of reservoir；The crack attribute data is used to characterize the physical property characteristic in crack；The layer attribute data include
First fracture permeabgility, in-place permeability, formation porosity, formation thickness and original formation pressure；The first crack infiltration
Rate is for characterizing fracture permeabgility of the purpose reservoir under the original formation pressure；The method includes：
Based on the rock mechanics data and first fracture permeabgility, determine that the target gas well corresponding second is split
Stitch the first incidence relation between permeability and bottom pressure；Wherein, second fracture permeabgility is for characterizing the purpose
Fracture permeabgility of the reservoir under the bottom pressure；
Based on the in-place permeability, the formation porosity and the formation thickness and the crack attribute data,
When determining the production of the target gas well yield and the bottom pressure, first fracture permeabgility, the target gas well
Between between the second incidence relation；
According to first incidence relation and second incidence relation, the corresponding bottom pressure of the target gas well is determined
With the correspondence of production time.
In preferred embodiment, the method is also provided with the general formula coefficient of rock in the purpose reservoir；Wherein, the general formula
Coefficient is for characterizing formation hardness；Determine first between corresponding second fracture permeabgility of the target gas well and bottom pressure
Incidence relation, including：
Based on wet coefficient and Poisson's ratio and first fracture permeabgility is finished in the rock mechanics data, determine
Incidence relation between corresponding second fracture permeabgility of the target gas well and permeability stress sensitive parameter；
General formula coefficient based on the rock, determines between the permeability stress sensitive parameter and the bottom pressure
Incidence relation；
According to incidence relation between second fracture permeabgility and the permeability stress sensitive parameter and described
Incidence relation between permeability stress sensitive parameter and the bottom pressure determines first incidence relation.
In preferred embodiment, determine that corresponding second fracture permeabgility of the target gas well is answered with permeability using following formula
Incidence relation between power sensitive parameter：
Δ p=pi-pw
Wherein, Kf(pw) and Kf(pi) second fracture permeabgility and first fracture permeabgility are indicated respectively；pwWith
piThe bottom pressure and the original formation pressure are indicated respectively；α and υ indicates described and finishes wet coefficient and the Poisson respectively
Than；(Δ p) indicates the permeability stress sensitive parameter to η；After Δ p indicates that the original formation pressure subtracts the bottom pressure
Obtained pressure difference；Wherein, the permeability stress sensitive parameter is associated with the pressure difference.
In preferred embodiment, when the general formula coefficient of the rock, which is greater than or equal to, specifies general formula coefficient threshold, use is following
Formula determines the incidence relation between the permeability stress sensitive parameter and the bottom pressure：
η (Δ p)=A Δs p+B
Δ p=pi-pw
Wherein, (Δ p) indicates the permeability stress sensitive parameter to η；pwAnd piThe bottom pressure and described is indicated respectively
Original formation pressure；Δ p indicates that the original formation pressure subtracts the pressure difference obtained after the bottom pressure；A and B is normal
Number；
When the general formula coefficient of the rock is less than the specified general formula coefficient threshold, oozed using described in the determination of following formula
Incidence relation between rate stress sensitive parameter and the bottom pressure thoroughly：
η (Δ p)=C
Wherein, C is constant.
In preferred embodiment, the method is also provided with the gas category under the original formation pressure of the purpose reservoir
Property data；Wherein, the gas properties data are used to characterize the physical property characteristic of gas in the purpose reservoir；Determine the target
Gas well yield and the bottom pressure, first fracture permeabgility, the target gas well production time between second
Incidence relation, including：
Based on splitting in the in-place permeability, the formation porosity, the formation thickness, the crack attribute data
Slit width degree and fracture half-length and the gas properties data, when determining that the target gas well yield is poor, quasi- with pseudopressure
Between, the incidence relation between first fracture permeabgility；Wherein, the pseudopressure difference indicates that the original formation pressure corresponds to
Pseudopressure and the corresponding pseudopressure of the bottom pressure difference；
Based on the gas properties data, the original formation pressure and the target gas well is corresponding is fifty-fifty laminated
Power determines the incidence relation between the pseudotime and the production time；
Based on the gas properties data and the original formation pressure, determine that the original formation pressure is corresponding respectively
Pseudopressure and the incidence relation and the corresponding pseudopressure of the bottom pressure of the original formation pressure and the bottom pressure
Incidence relation；
Being associated between, pseudotime poor with pseudopressure, first fracture permeabgility according to the target gas well yield
Incidence relation between relationship, the pseudotime and the production time and the corresponding pseudopressure of the original formation pressure
Pseudopressure corresponding with the incidence relation of the original formation pressure and the bottom pressure is associated with the bottom pressure
System, determines second incidence relation.
In preferred embodiment, poor the target gas well yield and pseudopressure, pseudotime, described the are determined using following formula
Incidence relation between one fracture permeabgility：
Wherein, q indicates the target gas well yield；m(pi)-m(pw) indicate that the pseudopressure is poor, m (pi) and m (pw)
The corresponding pseudopressure of the original formation pressure and the corresponding pseudopressure of the bottom pressure are indicated respectively；pwAnd piIt indicates respectively
The bottom pressure and the original formation pressure；nsIt indicates to carry out staged fracturing treated fracturing section to the target gas well
Quantity, nfIndicate the crack quantity in a fracturing section, wfAnd xfThe crack in the crack attribute data is indicated respectively
Width and fracture half-length；Kf(pi) indicate first fracture permeabgility；KmIndicate that the in-place permeability, h indicate the stratum
Thickness, φmIndicate the formation porosity, ηmiIndicate the stratum diffusion under the original formation pressure of the purpose reservoir
Coefficient；Bgi、μgiAnd cgiGas volume factor, gas viscosity and the gas compression system in the gas properties data are indicated respectively
Number；taIndicate the pseudotime.
In preferred embodiment, the incidence relation between the pseudotime and the production time is determined using following formula：
Wherein, taIndicate the pseudotime；μgiIndicate the gas viscosity in the gas properties data,It indicates in institute
State the amendment gas compressibility factor under original formation pressure, piIndicate the original formation pressure, μg[pavg(τ)] it indicates described
Gas viscosity under the corresponding mean reservoir pressure of target gas well,It indicates to correspond in the target gas well
Mean reservoir pressure under amendment gas compressibility factor, pavg(τ) indicates the corresponding mean reservoir pressure of the target gas well,
The mean reservoir pressure is associated with the production time；τ indicates that time variable to be integrated, t indicate the production time.
In preferred embodiment, using being associated with for the corresponding pseudopressure of bottom pressure described in following formula and the bottom pressure
System：
Wherein, m (pw) the corresponding pseudopressure of the bottom pressure is indicated respectively；μgiIt indicates in the gas properties data
Gas viscosity,Indicate the amendment Gaseous Z-factor under the original formation pressure, piIt is primitively laminated described in indicating
Power, ξ indicate pressure variations to be integrated, μg(ξ) indicates the amendment gas viscosity in the case where pressure value is the bottom pressure of ξ,Indicate the amendment Gaseous Z-factor in the case where pressure value is the bottom pressure of ξ, pscIndicate standard atmospheric pressure, pwIt indicates
The bottom pressure.
In preferred embodiment, the correspondence of the target gas well corresponding bottom pressure and production time is determined, including：
According to first incidence relation and second incidence relation, the target gas well yield and the well are determined
Incidence relation between bottom pressure, the production time；
According to the target gas well yield and the incidence relation between the bottom pressure, the production time, respectively
Determine that multiple specified production times correspond to the relation curve of multiple the target gas well yields and bottom pressure, and determination is each
The corresponding target bottom pressure of maximum point in the relation curve；Wherein, the specified production time and the relationship are bent
Line corresponds；
Processing is fitted to the specified production time and the target bottom pressure, the target gas well is obtained and corresponds to
Bottom pressure and production time correspondence.
Determine that the device of the bottom pressure of shale gas well and the correspondence of time, described device provide mesh in purpose work area
Reservoir layer attribute data, crack attribute data and rock mechanics data；Wherein, the purpose work area includes boring to meet institute
State the target gas well of purpose reservoir；The crack attribute data is used to characterize the physical property characteristic in crack；The layer attribute data
Include the first fracture permeabgility, in-place permeability, formation porosity, formation thickness and original formation pressure；Described first splits
Seam permeability is for characterizing fracture permeabgility of the purpose reservoir under the original formation pressure；Described device includes：The
One incidence relation determining module, the second incidence relation determining module and target correspondence determining module；Wherein,
The first incidence relation determining module, for being permeated based on the rock mechanics data and first crack
Rate determines the first incidence relation between corresponding second fracture permeabgility of the target gas well and bottom pressure；Wherein, described
Second fracture permeabgility is for characterizing fracture permeabgility of the purpose reservoir under the bottom pressure；
The second incidence relation determining module, for based on the in-place permeability, the formation porosity and described
Formation thickness and the crack attribute data determine that the target gas well yield is split with the bottom pressure, described first
Stitch permeability, the target gas well production time between the second incidence relation；
The target correspondence determining module is used for according to first incidence relation and second incidence relation,
Determine the correspondence of the target gas well corresponding bottom pressure and production time.
By the above technical solution provided by the embodiments of the present application as it can be seen that determining shale gas well provided by the embodiments of the present application
The method and device of bottom pressure and the correspondence of time can be based on the rock mechanics data and first crack is oozed
Saturating rate determines the first incidence relation between corresponding second fracture permeabgility of the target gas well and bottom pressure, can be with
Based on the in-place permeability, the formation porosity and the formation thickness and the crack attribute data, determine described in
Target gas well yield and the bottom pressure, first fracture permeabgility, the target gas well production time between
Second incidence relation；Finally, the target gas well can be determined according to first incidence relation and second incidence relation
The correspondence of corresponding bottom pressure and production time.In this way, the application method can in conjunction with shale gas reservoir variously
Layer attribute data, rock mechanics data and crack attribute data, establish a set of scientific and reasonable gas well liquid loading system prioritization scheme,
To obtain the correspondence of optimal bottom pressure and production time, so as to improve the ultimate recoverable reserves of shale gas well.
Description of the drawings
In order to illustrate the technical solutions in the embodiments of the present application or in the prior art more clearly, to embodiment or will show below
There is attached drawing needed in technology description to be briefly described, it should be apparent that, the accompanying drawings in the following description is only this
Some embodiments described in application, for those of ordinary skill in the art, in the premise of not making the creative labor property
Under, other drawings may also be obtained based on these drawings.
Fig. 1 is the flow for the embodiment of the method that the application determines the bottom pressure of shale gas well and the correspondence of time
Figure；
Fig. 2 is the schematic diagram of the physical model of multistage volume fracturing horizontal well in the embodiment of the present application；
Fig. 3 is the schematic diagram of the gas flow model in single crack in the embodiment of the present application；
Fig. 4 is the difference production time corresponding target gas well yield and bottom pressure in the embodiment of the present application
Relation curve schematic diagram；
Fig. 5 be the corresponding target gas well yield of the different production times in the embodiment of the present application in Fig. 4 and
The schematic diagram of the three productions system selected in the relation curve plate of bottom pressure；
Fig. 6 is the schematic diagram of the individual well cumulative production under three productions system respectively in the embodiment of the present application；
Fig. 7 is to produce the bottom pressure of gas well, formation pore pressure, total original place under system in the embodiment of the present application at two kinds
The schematic diagram of the situation of change of stress and effective stress；
Fig. 8 is a kind of embodiment for the device that the application determines the bottom pressure of shale gas well and the correspondence of time
Composite structural diagram；
Fig. 9 is another embodiment for the device that the application determines the bottom pressure of shale gas well and the correspondence of time
Composite structural diagram.
Specific implementation mode
The embodiment of the present application provides the method and device of the bottom pressure and the correspondence of time that determine shale gas well.
In order to make those skilled in the art better understand the technical solutions in the application, below in conjunction with the application reality
The attached drawing in example is applied, technical solutions in the embodiments of the present application is clearly and completely described, it is clear that described implementation
Example is merely a part but not all of the embodiments of the present application.Based on the embodiment in the application, this field is common
The every other embodiment that technical staff is obtained without creative efforts should all belong to the application protection
Range.
The method that the embodiment of the present application provides the bottom pressure and the correspondence of time of determining shale gas well.It is described true
The stratum of purpose reservoir in purposeful work area can be provided by determining the method for the bottom pressure of shale gas well and the correspondence of time
Attribute data, crack attribute data and rock mechanics data；Wherein, the purpose work area includes boring to meet the purpose reservoir
Target gas well；The crack attribute data is used to characterize the physical property characteristic in crack；The layer attribute data include first splitting
Stitch permeability, in-place permeability, formation porosity, formation thickness and original formation pressure；First fracture permeabgility is used for
Characterize fracture permeabgility of the purpose reservoir under the original formation pressure.Moreover, the determining shale gas well
The method of bottom pressure and the correspondence of time can also be provided with the gas properties data under the original formation pressure；
Wherein, the gas properties data are used to characterize the physical property characteristic of gas in the purpose reservoir.
In the present embodiment, the purpose work area can refer to waiting exploitation or work area being developed.For example, Sichuan
Basin shale gas producing region.The work area includes shale gas reservoir, i.e., the described purpose reservoir.The work area further includes boring to meet the purpose
The target gas well of reservoir.The target gas well can refer to the drilling well opened up in the purpose reservoir.
In the present embodiment, the method with experimental test can be tested by mining site, obtain the ground of the purpose reservoir
Layer attribute data, crack attribute data, rock mechanics data and the gas properties data under the original formation pressure.These
Data generate certain influence to the bottom pressure and the correspondence of time that optimize shale gas well.Wherein, the well of shale gas well
The correspondence of bottom pressure and time may be generally referred to as the production system of shale gas well.
In the present embodiment, it can be obtained in the layer attribute data by the method for well testing and productivity test
In-place permeability and the first fracture permeabgility and the fracture width in the crack attribute data and fracture half-length.Wherein, institute
It states in-place permeability to be primarily referred to as after carrying out staged fracturing processing to horizontal well, the ground in the Effective Affecting Area domain of volume transformation
Layer effective permeability.Permeability in the area can be effectively improved, in this way, effective flowing can occur for gas.Institute
State crack be primarily referred to as to horizontal well carry out staged fracturing processing when, supported by proppant to be formed have one fixed width and
The man-made fracture of length.
In the present embodiment, can be by the methods of test and the static pressure test of logging well, and calculated using empirical equation
To in the layer attribute data original formation pressure, in formation porosity and the target gas well net horizontal section length
Degree and well spacing.The rock mechanics data can also be obtained by rock core triaxiality stressh method.Wherein, the rock power
It may include finishing wet (Biot) coefficient, Poisson's ratio and Young's modulus etc. to learn data, these data can be used as permeability stress quick
Feel the influence factor of parameter.Permeability stress sensitive curve, i.e. crack can also be obtained by rock core stress sensitive experimental method
The relation curve of permeability ratio and effective stress, with for corresponding second fracture permeabgility of the subsequently determining target gas well with
Incidence relation between bottom pressure provides data basis.Wherein, fracture permeabgility ratio can refer to that second crack is oozed
The ratio of saturating rate and first fracture permeabgility, second fracture permeabgility is for characterizing the purpose reservoir in the well
Fracture permeabgility under bottom pressure.
In the present embodiment, the gas properties number can be obtained by high pressure property and adsorption isotherm experiment method
Gas volume factor, gas viscosity, gas compressibility factor in and youth's Ge Miaoer adsorption isothermal curves.
For example, developing gas well X1 for Sichuan Basin shale gas producing region mouth, the corresponding layer attribute of X1 wells can be obtained
Data, rock mechanics data and gas attribute data etc..Table 1 is the corresponding underlying parameter tables of data of X1 wells.
The corresponding underlying parameter tables of data of 1 X1 wells of table
Fig. 1 is the flow for the embodiment of the method that the application determines the bottom pressure of shale gas well and the correspondence of time
Figure.As shown in Figure 1, the method for the bottom pressure and the correspondence of time of the determining shale gas well, includes the following steps.
Step S101：Based on the rock mechanics data and first fracture permeabgility, the target gas well pair is determined
The first incidence relation between the second fracture permeabgility answered and bottom pressure；Wherein, second fracture permeabgility is used for table
Levy fracture permeabgility of the purpose reservoir under the bottom pressure.
In the present embodiment, the method for the bottom pressure of the determining shale gas well and the correspondence of time can be with
It is provided with the general formula coefficient of rock in the purpose reservoir.Wherein, the general formula coefficient is for characterizing formation hardness.Correspondingly,
Based on the rock mechanics data and first fracture permeabgility, corresponding second fracture permeabgility of the target gas well is determined
The first incidence relation between bottom pressure, can specifically include, can be based on the complete wet system in the rock mechanics data
Number and Poisson's ratio and first fracture permeabgility determine corresponding second fracture permeabgility of the target gas well and infiltration
Incidence relation between rate stress sensitive parameter.General formula coefficient based on the rock determines the permeability stress sensitive ginseng
Several incidence relations between the bottom pressure.It can be according to second fracture permeabgility and the permeability stress sensitive
The incidence relation between incidence relation and the permeability stress sensitive parameter and the bottom pressure between parameter, really
Fixed first incidence relation.Wherein, second fracture permeabgility is for characterizing the purpose reservoir in the bottom pressure
Under fracture permeabgility.
In the present embodiment, may be used following formula determine corresponding second fracture permeabgility of the target gas well with
Incidence relation between permeability stress sensitive parameter：
Δ p=pi-pw
Wherein, Kf(pw) and Kf(pi) second fracture permeabgility and first fracture permeabgility are indicated respectively；pwWith
piThe bottom pressure and the original formation pressure are indicated respectively；α and υ indicates described and finishes wet coefficient and the Poisson respectively
Than；(Δ p) indicates the permeability stress sensitive parameter to η；After Δ p indicates that the original formation pressure subtracts the bottom pressure
Obtained pressure difference；Wherein, the permeability stress sensitive parameter is associated with the pressure difference.
It in the present embodiment, can be with when the general formula coefficient of the rock, which is greater than or equal to, specifies general formula coefficient threshold
The incidence relation between the permeability stress sensitive parameter and the bottom pressure is determined using following formula：
η (Δ p)=A Δs p+B
Δ p=pi-pw
Wherein, (Δ p) indicates the permeability stress sensitive parameter to η；pwAnd piThe bottom pressure and described is indicated respectively
Original formation pressure；Δ p indicates that the original formation pressure subtracts the pressure difference obtained after the bottom pressure；A and B is normal
Number.
When the general formula coefficient of the rock is less than the specified general formula coefficient threshold, following formula may be used and determine institute
State the incidence relation between permeability stress sensitive parameter and the bottom pressure：
η (Δ p)=C
Wherein, C is constant.Constant A, B and C specifically can be according to the fracture permeabgility ratios of the core sample of different hardness
It is determined with the relation curve of effective stress.
In the present embodiment, the value range of the specified general formula coefficient threshold can be 2~3.
Step S102：Based on the in-place permeability, the formation porosity and the formation thickness and the crack
Attribute data determines the target gas well yield and the bottom pressure, first fracture permeabgility, the target gas well
Production time between the second incidence relation.
In the present embodiment, Fig. 2 is the signal of the physical model of multistage volume fracturing horizontal well in the embodiment of the present application
Figure.Fig. 3 is the schematic diagram of the gas flow model in single crack in the embodiment of the present application.It can be as shown in Figures 2 and 3
On the basis of gas flow model in the physical model and single crack of multistage volume fracturing horizontal well, oozed based on the stratum
Saturating rate, the formation porosity and the formation thickness and the crack attribute data, determine the target gas well yield
With the bottom pressure, first fracture permeabgility, the target gas well production time between the second incidence relation.Its
In, the physical model of the multistage volume fracturing horizontal well is with defined below：(1) the uniform uniform thickness in stratum, gas mainly flow
Region is present between man-made fracture；(2) in-place permeability is extremely low, not by crack interference effect (3) horizontal well in flow event
Pressure break nfSection, form n in every sectionsCrack, man-made fracture is uniformly distributed, attribute is identical；(4) man-made fracture up and down completely through
Stratum has flow conductivity.As shown in Figures 2 and 3, crack is perpendicular to the direction of horizontal wellbore, gas from stratum by desorption,
The modes such as elastic compression, along crack to Wellbore Flow, are finally plucked out of to flow in fracture after flowing into crack.In figure 2 and figure 3,
Fracture half-length is xf, fracture interval xs, fracture length 2xf, formation thickness h.SRV width means volumes transformation in Fig. 2
Effective Affecting Area domain width, single-stage length LsFor the length of each fracturing section, i.e. horizontal wellbore length LwDivided by horizontal well pressure
Split the quantity n of sectionfValue, fracture interval xsFor single-stage length LsDivided by the quantity n of each fracturing section internal fissuresValue.In Fig. 3
Grey cube indicate crack, grey columns body surface shows horizontal wellbore.
In the present embodiment, it is based on the physical model, is existed according to gas percolation law in the earth formation and gas
Percolation law in crack can establish the bilinear flow mathematical model that gas flows into crack from stratum, flows into pit shaft from crack,
It is namely based on the in-place permeability, the formation porosity and the formation thickness and the crack attribute data, really
The production time of fixed the target gas well yield and the bottom pressure, first fracture permeabgility, the target gas well
Between the second incidence relation, can specifically determine as steps described below：
(1), it is based in the in-place permeability, the formation porosity, the formation thickness, the crack attribute data
Fracture width and fracture half-length and the gas properties data, determine that the target gas well yield and pseudopressure are poor, quasi-
Incidence relation between time, first fracture permeabgility；Wherein, the pseudopressure difference indicates the original formation pressure pair
The difference of the corresponding pseudopressure of the pseudopressure and the bottom pressure answered；
(2), the gas properties data, the original formation pressure and the corresponding average stratum of the target gas well are based on
Pressure determines the incidence relation between the pseudotime and the production time；
(3), it is based on the gas properties data and the original formation pressure, determines the original formation pressure pair respectively
The pseudopressure answered and the incidence relation and the corresponding pseudopressure of the bottom pressure of the original formation pressure and the shaft bottom
The incidence relation of pressure；
(4), according to the target gas well yield and pseudopressure between poor, pseudotime, first fracture permeabgility
Incidence relation and the original formation pressure between incidence relation, the pseudotime and the production time is corresponding quasi-
The pass of pressure corresponding with the incidence relation of the original formation pressure and the bottom pressure pseudopressure and the bottom pressure
Connection relationship determines second incidence relation.
In the present embodiment, poor the target gas well yield and pseudopressure, pseudotime, institute are determined using following formula
State the incidence relation between the first fracture permeabgility：
Wherein, q indicates the target gas well yield；m(pi)-m(pw) indicate that the pseudopressure is poor, m (pi) and m (pw)
The corresponding pseudopressure of the original formation pressure and the corresponding pseudopressure of the bottom pressure are indicated respectively；pwAnd piIt indicates respectively
The bottom pressure and the original formation pressure；nsIt indicates to carry out staged fracturing treated fracturing section to the target gas well
Quantity, nfIndicate the crack quantity in a fracturing section, wfAnd xfThe crack in the crack attribute data is indicated respectively
Width and fracture half-length；Kf(pi) indicate first fracture permeabgility；KmIndicate that the in-place permeability, h indicate the stratum
Thickness, φmIndicate the formation porosity, ηmiIndicate the stratum diffusion under the original formation pressure of the purpose reservoir
Coefficient；Bgi、μgiAnd cgiGas volume factor, gas viscosity and the gas compression system in the gas properties data are indicated respectively
Number；taIndicate the pseudotime.
In the present embodiment, following formula may be used and determine being associated between the pseudotime and the production time
Relationship：
Wherein, taIndicate the pseudotime；μgiIndicate the gas viscosity in the gas properties data,It indicates in institute
State the amendment gas compressibility factor under original formation pressure, piIndicate the original formation pressure, μg[pavg(τ)] it indicates described
Gas viscosity under the corresponding mean reservoir pressure of target gas well,It indicates to correspond in the target gas well
Mean reservoir pressure under amendment gas compressibility factor, pavg(τ) indicates the corresponding mean reservoir pressure of the target gas well,
The mean reservoir pressure is associated with the production time；τ indicates that time variable to be integrated, t indicate the production time.
In the present embodiment, the corresponding pseudopressure of bottom pressure described in following formula and the bottom pressure may be used
Incidence relation：
Wherein, m (pw) the corresponding pseudopressure of the bottom pressure is indicated respectively；μgiIt indicates in the gas properties data
Gas viscosity,Indicate the amendment Gaseous Z-factor under the original formation pressure, piIt is primitively laminated described in indicating
Power, ξ indicate pressure variations to be integrated, μg(ξ) indicates the amendment gas viscosity in the case where pressure value is the bottom pressure of ξ,Indicate the amendment Gaseous Z-factor in the case where pressure value is the bottom pressure of ξ, pscIndicate standard atmospheric pressure, pwIt indicates
The bottom pressure.
Similarly, the corresponding pseudopressure of original formation pressure described in following formula and the original formation pressure may be used
Incidence relation：
Wherein, m (pi) the corresponding pseudopressure of the bottom pressure is indicated respectively；μgiIt indicates in the gas properties data
Gas viscosity,Indicate the amendment Gaseous Z-factor under the original formation pressure, piIt is primitively laminated described in indicating
Power, pscIndicate that standard atmospheric pressure, ξ indicate pressure variations to be integrated, μg(ξ) is indicated in the original formation pressure that pressure value is ξ
Under amendment gas viscosity,Indicate the amendment Gaseous Z-factor in the case where pressure value is the original formation pressure of ξ.
In the present embodiment, following formula may be used and determine the mean reservoir pressure：
Wherein, pavgIndicate the corresponding mean reservoir pressure of the target gas well,Indicate it is described fifty-fifty
Amendment Gaseous Z-factor under stressor layer,Indicate the amendment Gaseous Z-factor under the original formation pressure, piTable
Show the original formation pressure, KmIndicate that the in-place permeability, h indicate the formation thickness, φmIndicate the formation pore
Degree, Bgi、μgiAnd cgiGas volume factor, gas viscosity and the gas compressibility factor in the gas properties data are indicated respectively；
xfIndicate the fracture half-length in the crack attribute data；M indicated yield modified quasi pressure difference and between the radical sign lower production time
Fitting a straight line slope.The yield modified quasi pressure difference may be usedIt indicates, the radical sign
The lower production time may be usedTo indicate, wherein t indicates the production time.
In the present embodiment, following formula may be used and determine the amendment Gaseous Z-factor under specified pressure respectively
With amendment gas compressibility factor：
Wherein, p indicates the specified pressure, can be the mean reservoir pressure pavg, the original formation pressure piOr
The bottom pressure pw；WithIt the amendment Gaseous Z-factor that is illustrated respectively under the specified pressure and repaiies
Positive gas compressibility factor, Zg(p) and cg(p) Gaseous Z-factor and gas compressibility factor under the specified pressure are indicated；Bg
(p) gas volume factor under the specified pressure, V are indicatedLAnd pLBlue formula pressure and blue co-volume, φ are indicated respectivelymIt indicates
The formation porosity.
Step S103：According to first incidence relation and second incidence relation, determine that the target gas well corresponds to
Bottom pressure and production time correspondence.
In the present embodiment, according to first incidence relation and second incidence relation, the target gas is determined
The correspondence of well corresponding bottom pressure and production time, can specifically include, can according to first incidence relation and
Second incidence relation determines the target gas well yield and being associated between the bottom pressure, the production time
Relationship.It can be according to the target gas well yield and the incidence relation between the bottom pressure, the production time, respectively
Determine that multiple specified production times correspond to the relation curve of multiple the target gas well yields and bottom pressure, and determination is each
The corresponding target bottom pressure of maximum point in the relation curve.Wherein, the specified production time and the relationship are bent
Line corresponds.Processing can be fitted to the specified production time and the target bottom pressure, obtain the target
The correspondence of gas well corresponding bottom pressure and production time.
In the present embodiment, may be used following formula determine the target gas well yield and the bottom pressure,
Incidence relation between the production time：
Wherein, q indicates the target gas well yield；m(pi)-m(pw) indicate that the pseudopressure is poor, m (pi) and m (pw)
The corresponding pseudopressure of the original formation pressure and the corresponding pseudopressure of the bottom pressure are indicated respectively；pwAnd piIt indicates respectively
The bottom pressure and the original formation pressure；α and υ indicates described and finishes wet coefficient and the Poisson's ratio respectively；η (Δ p) tables
Show the permeability stress sensitive parameter；Δ p indicates that the original formation pressure subtracts the pressure obtained after the bottom pressure
Difference；nsIndicate to carry out the target gas well quantity of staged fracturing treated fracturing section, nfIt indicates in a fracturing section
Crack quantity, wfAnd xfThe fracture width in the crack attribute data and fracture half-length are indicated respectively；Kf(pw) described in expression
Second fracture permeabgility；KmIndicate that the in-place permeability, h indicate the formation thickness, φmIndicate the formation porosity,
ηmiIndicate the stratum diffusion coefficient under the original formation pressure of the purpose reservoir；Bgi、μgiAnd cgiDescribed in indicating respectively
Gas volume factor, gas viscosity in gas properties data and gas compressibility factor；taIndicate the pseudotime.
In the present embodiment, according to the target gas well yield and between the bottom pressure, the production time
Incidence relation, determine that multiple specified production times correspond to the relationships of multiple the target gas well yields and bottom pressure respectively
Curve can specifically include, and can obtain one group of creation data respectively from the Production development data of the target gas well.Its
In, this group of creation data includes the data of pseudopressure difference and corresponding production time.Then, according to quasi- in this group of creation data
Pressure difference and corresponding production time determine yield modified quasi pressure difference and radical sign lower production time respectively.In this way, can obtain
Include yield modified quasi pressure difference and the data of radical sign lower production time to one group, wherein yield modified quasi pressure difference and radical sign
The lower production time will correspond.Then, multiple yield modified quasi pressure differences and the data point of radical sign lower production time can be painted
It makes in rectangular coordinate system, using the method for linear regression analysis, determines and produced under the yield modified quasi pressure difference and radical sign
The slope M of fitting a straight line between time.The slope M is substituted into the corresponding formula of the determination mean reservoir pressure
In, different specified production times t corresponding mean reservoir pressure p can be obtainedavg, and then when obtaining different specified production
Between the corresponding pseudotime t of ta.Finally, by difference specified production time t corresponding pseudotime taSubstitute into the target gas
The corresponding formula of incidence relation between well yield and the bottom pressure, the production time, can obtain multiple specified
Production time corresponds to the relation curve of multiple the target gas well yields and bottom pressure.
For example, Fig. 4 is the difference production time corresponding target gas well yield and well in the embodiment of the present application
The schematic diagram of the relation curve of bottom pressure.Abscissa and ordinate in Fig. 4 are respectively bottom pressure and the individual well daily output, unit
Respectively megapascal (MPa) and all places/day.As shown in figure 4, can be according to 6 difference production times corresponding target
The relation curve of gas well yield and bottom pressure determines the corresponding target shaft bottom of maximum point in each relation curve
Pressure.Then processing can be fitted to multiple production times and multiple target bottom pressures, obtain the target gas well again
The correspondence of corresponding bottom pressure and production time, i.e., the Optimal Production system of the described target gas well.
In one embodiment of the application, the side of the bottom pressure and the correspondence of time of the determining shale gas well
Method can also include：It can be according to the corresponding bottom pressure of the target gas well and the correspondence of production time and described first
Incidence relation establishes overall process production performance model of the target gas well under the Optimal Production system.It specifically, can be with
It will be substituted into for the formula of the corresponding bottom pressure of the target gas well and the correspondence of production time for characterizing described the
In the formula of one incidence relation, and in view of changing the nonhomogeneous influence brought on gas well liquid loading after production system, breathed out using Du
Beautiful (Duhamel) convolution method, establishes overall process production performance model of the target gas well under the Optimal Production system.
In the present embodiment, the entire gas well liquid loading period can be divided into n production time section.It may be used following
Formula establishes overall process production performance model of the target gas well under the Optimal Production system：
Δpj=pw,j-1-pw,j
Wherein, q indicates the target gas well yield；m(pw,j) expression pressure value be pw,jBottom pressure it is corresponding quasi-
Pressure；pw,jIndicate j-th of production time corresponding target bottom pressure, wherein as j=1, pw,j-1For the prime stratum
Pressure pi；α and υ indicates described and finishes wet coefficient and the Poisson's ratio respectively；(Δ p) indicates the permeability stress sensitive parameter to η；
Δ p indicates that the original formation pressure subtracts the pressure difference obtained after the bottom pressure；nsIndicate to the target gas well into
The quantity of row staged fracturing treated fracturing section, nfIndicate the crack quantity in a fracturing section, wfAnd xfIt indicates respectively
Fracture width in the crack attribute data and fracture half-length；Kf(pw,j-1) indicate that in pressure value be pw,jBottom pressure under
Fracture permeabgility, wherein as j=1, Kf(pw,j-1) it is in first fracture permeabgility；KmIndicate the stratum infiltration
Rate, h indicate the formation thickness, φmIndicate the formation porosity, ηmiIndicate the purpose reservoir in the prime stratum
Stratum diffusion coefficient under pressure；Bgi、μgiAnd cgiGas volume factor, the gas in the gas properties data are indicated respectively
Viscosity and gas compressibility factor；ta,jIndicate j-th of production time corresponding pseudotime.
It in the present embodiment, can be to production time section in the mean reservoir pressure of each production time section of determination
The modified fitting pressure difference of interior yield is fitted processing with the radical sign lower production time, obtains the slope of corresponding fitting a straight line
M, and then determine corresponding mean reservoir pressure.In this way, slope M can carry out real-time update according to production time section.
For example, Fig. 5 is the production of the corresponding target gas well of different production times in the embodiment of the present application in Fig. 4
The schematic diagram of the three productions system selected in the relation curve plate of amount and bottom pressure.Fig. 6 is divided in the embodiment of the present application
The schematic diagram of individual well cumulative production not under three productions system.Abscissa and ordinate in Fig. 5 are respectively bottom pressure
With the individual well daily output, unit is respectively megapascal (MPa) and all places/day.Abscissa and ordinate in Fig. 6 are respectively the production time
With individual well cumulative production, unit is respectively year and hundred million sides.Path optimizing 1 in Fig. 5 and Fig. 6 is the production system for bleeding off pressure the mode of production
Degree, path optimizing 2 are the Optimal Production system that the application method determines, path optimizing 3 is the life of the unreasonable pressure control mode of production
Production system.As shown in fig. 6, in production early stage, that is, the production time section in Fig. 6 before dash-dotted gray line, bleed off pressure the mode of production
Production system can obtain higher cumulative production, and enter after the production middle and later periods, that is, in Fig. 6 after dash-dotted gray line
Production time section, the Optimal Production system determined using the application method, gas well can obtain higher cumulative production, with
The increase of production time, Optimal Production system are more and more significant to the raising effect of gas well cumulative production.As a comparison, do not conforming to
Gas well cumulative production under the production system of the pressure control mode of production of reason will be less than production system and the use for bleeding off pressure the mode of production
The Optimal Production system that the application method determines illustrates gas well liquid loading effect may be caused low using improperly pressure control production decision
In bleeding off pressure production decision.
Fig. 7 is to produce the bottom pressure of gas well, formation pore pressure, total original place under system in the embodiment of the present application at two kinds
The schematic diagram of the situation of change of stress and effective stress.The path optimizing 1 of (a) and (b) respectively in Figure 5 is corresponding in Fig. 7
The bottom pressure of gas well, formation pore pressure, total Original strata stress and have under 2 corresponding production system of production system and path optimizing
The schematic diagram of the situation of change of efficacy.Abscissa and ordinate in Fig. 7 in (a) and (b) are respectively production time and pressure,
Unit is respectively day and megapascal (MPa).As shown in fig. 7, by producing system control, can effectively influence in stratum or crack
The version of effective stress, in particular, can effectively inhibit the increasing of effective stress using 2 corresponding production system of path optimizing
Add amplitude, so that seepage channel is maintained for a long time interior unlatching, thereby may be ensured that gas well capacity.
Table 2 is ultimate recoverable reserves (the Estimated Ultimate of the similar three implications well of Geological Engineering background
Recovery, EUR).Wherein, three implication wells are respectively shale well X1, X2 and X3.Three implication wells respectively use excellent in Fig. 5
Change the corresponding production system for bleeding off pressure the mode of production in path 1 and 2 corresponding Optimal Production system of path optimizing carries out control production.
Normalization EUR in table 2 indicates the ratio of EUR and effective mining-employed reserves, and EUR, which increases ratio, to be Optimal Production system and bleed off pressure life
Difference between the corresponding EUR of production system, the ratio of EUR corresponding with production system is bled off pressure.
The ultimate recoverable reserves of the similar three implications well of 2 Geological Engineering background of table
From Table 2, it can be seen that individual well EUR can effectively improve using the Optimal Production system that the application method determines,
Achieve the purpose that improve Well Development effect.
The embodiment of the method for the bottom pressure and the correspondence of time of the determining shale gas well can be based on the rock
Stone Mechanical Data and first fracture permeabgility determine corresponding second fracture permeabgility of the target gas well and bottom pressure
Between the first incidence relation, be also based on the in-place permeability, the formation porosity and the formation thickness, and
The crack attribute data determines the target gas well yield and the bottom pressure, first fracture permeabgility, described
The second incidence relation between the production time of target gas well；It finally, can be according to first incidence relation and described second
Incidence relation determines the correspondence of the target gas well corresponding bottom pressure and production time.In this way, the application method can
To combine various layer attribute data, rock mechanics data and the crack attribute data of shale gas reservoir, establishes a set of science and close
The gas well liquid loading system prioritization scheme of reason, to obtain the correspondence of optimal bottom pressure and production time, so as to carry
The ultimate recoverable reserves of high shale gas well.
Fig. 8 is a kind of embodiment for the device that the application determines the bottom pressure of shale gas well and the correspondence of time
Composite structural diagram.The bottom pressure of the determining shale gas well and the device of the correspondence of time provide purpose in purpose work area
Layer attribute data, crack attribute data and the rock mechanics data of reservoir；Wherein, the purpose work area includes boring described in chance
The target gas well of purpose reservoir；The crack attribute data is used to characterize the physical property characteristic in crack；In the layer attribute data
Including the first fracture permeabgility, in-place permeability, formation porosity, formation thickness and original formation pressure；First crack
Permeability is for characterizing fracture permeabgility of the purpose reservoir under the original formation pressure.As shown in figure 8, the determination
The device of the bottom pressure of shale gas well and the correspondence of time may include：First incidence relation determining module 100, second
Incidence relation determining module 200 and target correspondence determining module 300.
The first incidence relation determining module 100 can be used for splitting based on the rock mechanics data and described first
Permeability is stitched, determines the first incidence relation between corresponding second fracture permeabgility of the target gas well and bottom pressure；Its
In, second fracture permeabgility is for characterizing fracture permeabgility of the purpose reservoir under the bottom pressure.
The second incidence relation determining module 200 can be used for based on the in-place permeability, the formation porosity
With the formation thickness and the crack attribute data, the target gas well yield and the bottom pressure, described are determined
First fracture permeabgility, the target gas well production time between the second incidence relation.
The target correspondence determining module 300 can be used for being closed according to first incidence relation and described second
Connection relationship determines the correspondence of the target gas well corresponding bottom pressure and production time.
Fig. 9 is another embodiment for the device that the application determines the bottom pressure of shale gas well and the correspondence of time
Composite structural diagram.As shown in figure 9, the bottom pressure of the determining shale gas well and the device of the correspondence of time can wrap
Memory, processor and the computer program being stored on the memory are included, purposeful work area is stored in the memory
Layer attribute data, crack attribute data and the rock mechanics data of middle purpose reservoir；Wherein, the purpose work area includes boring
Meet the target gas well of the purpose reservoir；The crack attribute data is used to characterize the physical property characteristic in crack；The layer attribute
Data include the first fracture permeabgility, in-place permeability, formation porosity, formation thickness and original formation pressure；Described
One fracture permeabgility is for characterizing fracture permeabgility of the purpose reservoir under the original formation pressure, the computer journey
Sequence executes following steps when being run by the processor：
Step S101：Based on the rock mechanics data and first fracture permeabgility, the target gas well pair is determined
The first incidence relation between the second fracture permeabgility answered and bottom pressure；Wherein, second fracture permeabgility is used for table
Levy fracture permeabgility of the purpose reservoir under the bottom pressure；
Step S102：Based on the in-place permeability, the formation porosity and the formation thickness and the crack
Attribute data determines the target gas well yield and the bottom pressure, first fracture permeabgility, the target gas well
Production time between the second incidence relation；
Step S103：According to first incidence relation and second incidence relation, determine that the target gas well corresponds to
Bottom pressure and production time correspondence.
The bottom pressure of the determining shale gas well and the device embodiment of the correspondence of time and the determining shale
The bottom pressure of gas well is corresponding with the embodiment of the method for the correspondence of time, and the shaft bottom pressure for determining shale gas well may be implemented
The technical solution of the embodiment of the method for the correspondence of power and time, and the technique effect of adquisitiones embodiment.
In the 1990s, the improvement of a technology can be distinguished clearly be on hardware improvement (for example,
Improvement to circuit structures such as diode, transistor, switches) or software on improvement (improvement for method flow).So
And with the development of technology, the improvement of current many method flows can be considered as directly improving for hardware circuit.
Designer nearly all obtains corresponding hardware circuit by the way that improved method flow to be programmed into hardware circuit.Cause
This, it cannot be said that the improvement of a method flow cannot be realized with hardware entities module.For example, programmable logic device
(Programmable Logic Device, PLD) (such as field programmable gate array (Field Programmable Gate
Array, FPGA)) it is exactly such a integrated circuit, logic function determines device programming by user.By designer
Voluntarily programming comes a digital display circuit " integrated " on a piece of PLD, designs and makes without asking chip maker
Dedicated IC chip.Moreover, nowadays, substitution manually makes IC chip, this programming is also used instead mostly " patrols
Volume compiler (logic compiler) " software realizes that software compiler used is similar when it writes with program development,
And the source code before compiling also write by handy specific programming language, this is referred to as hardware description language
(Hardware Description Language, HDL), and HDL is also not only a kind of, but there are many kind, such as ABEL
(Advanced Boolean Expression Language)、AHDL(Altera Hardware Description
Language)、Confluence、CUPL(Cornell University Programming Language)、HDCal、JHDL
(Java Hardware Description Language)、Lava、Lola、MyHDL、PALASM、RHDL(Ruby
Hardware Description Language) etc., VHDL (Very-High-Speed are most generally used at present
Integrated Circuit Hardware Description Language) and Verilog2.Those skilled in the art
It will be apparent to the skilled artisan that only needing method flow slightly programming in logic and being programmed into integrated circuit with above-mentioned several hardware description languages
In, so that it may to be readily available the hardware circuit for realizing the logical method flow.
It is also known in the art that other than realizing controller in a manner of pure computer readable program code, it is complete
Entirely can by by method and step carry out programming in logic come so that controller with logic gate, switch, application-specific integrated circuit, programmable
The form of logic controller and embedded microcontroller etc. realizes identical function.Therefore this controller is considered one kind
Hardware component, and the structure that the device for realizing various functions for including in it can also be considered as in hardware component.Or
Even, can will be considered as realizing the device of various functions either the software module of implementation method can be Hardware Subdivision again
Structure in part.
Device that above-described embodiment illustrates, module can specifically realize by computer chip or entity, or by having certain
The product of function is planted to realize.
For convenience of description, it is divided into various modules when description apparatus above with function to describe respectively.Certainly, implementing this
The function of each module is realized can in the same or multiple software and or hardware when application.
As seen through the above description of the embodiments, those skilled in the art can be understood that the application can
It is realized by the mode of software plus required general hardware platform.Based on this understanding, the technical solution essence of the application
On in other words the part that contributes to existing technology can be expressed in the form of software products, in a typical configuration
In, computing device includes one or more processors (CPU), input/output interface, network interface and memory.The computer is soft
Part product may include that some instructions are used so that a computer equipment (can be personal computer, server or network
Equipment etc.) execute method described in certain parts of each embodiment of the application or embodiment.The computer software product can
To store in memory, memory may include the volatile memory in computer-readable medium, random access memory
(RAM) and/or the forms such as Nonvolatile memory, such as read-only memory (ROM) or flash memory (flash RAM).Memory is computer
The example of readable medium.Computer-readable medium includes that permanent and non-permanent, removable and non-removable media can be by
Any method or technique realizes information storage.Information can be computer-readable instruction, data structure, the module of program or its
His data.The example of the storage medium of computer includes, but are not limited to phase transition internal memory (PRAM), static RAM
(SRAM), dynamic random access memory (DRAM), other kinds of random access memory (RAM), read-only memory
(ROM), electrically erasable programmable read-only memory (EEPROM), fast flash memory bank or other memory techniques, CD-ROM are read-only
Memory (CD-ROM), digital versatile disc (DVD) or other optical storages, magnetic tape cassette, tape magnetic disk storage or
Other magnetic storage apparatus or any other non-transmission medium can be used for storage and can be accessed by a computing device information.According to
Herein defines, and computer-readable medium does not include of short duration computer readable media (transitory media), such as modulation
Data-signal and carrier wave.
Each embodiment in this specification is described in a progressive manner, identical similar portion between each embodiment
Point just to refer each other, and each embodiment focuses on the differences from other embodiments.Especially for device reality
For applying example, since it is substantially similar to the method embodiment, so description is fairly simple, related place is referring to embodiment of the method
Part explanation.
The application can be used in numerous general or special purpose computing system environments or configuration.Such as：Personal computer, clothes
Business device computer, handheld device or portable device, laptop device, multicomputer system, microprocessor-based system, set
Top box, programmable consumer-elcetronics devices, network PC, minicomputer, mainframe computer including any of the above system or equipment
Distributed computing environment etc..
The application can describe in the general context of computer-executable instructions executed by a computer, such as program
Module.Usually, program module includes routines performing specific tasks or implementing specific abstract data types, program, object, group
Part, data structure etc..The application can also be put into practice in a distributed computing environment, in these distributed computing environments, by
Task is executed by the connected remote processing devices of communication network.In a distributed computing environment, program module can be with
In the local and remote computer storage media including storage device.
Although depicting the application by embodiment, it will be appreciated by the skilled addressee that the application there are many deformation and
Variation is without departing from spirit herein, it is desirable to which the attached claims include these deformations and change without departing from the application's
Spirit.
Claims (10)
1. the method for determining the bottom pressure and the correspondence of time of shale gas well, which is characterized in that provide purposeful work area
Layer attribute data, crack attribute data and the rock mechanics data of middle purpose reservoir；Wherein, the purpose work area includes boring
Meet the target gas well of the purpose reservoir；The crack attribute data is used to characterize the physical property characteristic in crack；The layer attribute
Data include the first fracture permeabgility, in-place permeability, formation porosity, formation thickness and original formation pressure；Described
One fracture permeabgility is for characterizing fracture permeabgility of the purpose reservoir under the original formation pressure；The method packet
It includes：
Based on the rock mechanics data and first fracture permeabgility, determine that corresponding second crack of the target gas well is oozed
The first incidence relation between rate and bottom pressure thoroughly；Wherein, second fracture permeabgility is for characterizing the purpose reservoir
Fracture permeabgility under the bottom pressure；
Based on the in-place permeability, the formation porosity and the formation thickness and the crack attribute data, determine
The target gas well yield and the bottom pressure, first fracture permeabgility, the target gas well production time it
Between the second incidence relation；
According to first incidence relation and second incidence relation, the corresponding bottom pressure of the target gas well and life are determined
Produce the correspondence of time.
2. according to the method described in claim 1, it is characterized in that, the method is also provided with rock in the purpose reservoir
General formula coefficient；Wherein, the general formula coefficient is for characterizing formation hardness；Determine the corresponding second crack infiltration of the target gas well
The first incidence relation between rate and bottom pressure, including：
Based on wet coefficient and Poisson's ratio and first fracture permeabgility is finished in the rock mechanics data, determine described in
Incidence relation between corresponding second fracture permeabgility of target gas well and permeability stress sensitive parameter；
General formula coefficient based on the rock, determines being associated between the permeability stress sensitive parameter and the bottom pressure
Relationship；
According between second fracture permeabgility and the permeability stress sensitive parameter incidence relation and the infiltration
Incidence relation between rate stress sensitive parameter and the bottom pressure determines first incidence relation.
3. according to the method described in claim 2, it is characterized in that, determining the target gas well corresponding using following formula
Incidence relation between two fracture permeabgilitys and permeability stress sensitive parameter：
Δ p=pi-pw
Wherein, Kf(pw) and Kf(pi) second fracture permeabgility and first fracture permeabgility are indicated respectively；pwAnd piPoint
The bottom pressure and the original formation pressure are not indicated；α and υ indicates described and finishes wet coefficient and the Poisson's ratio respectively；η
(Δ p) indicates the permeability stress sensitive parameter；Δ p indicates to obtain after the original formation pressure subtracts the bottom pressure
Pressure difference；Wherein, the permeability stress sensitive parameter is associated with the pressure difference.
4. according to the method described in claim 2, it is characterized in that,
When the general formula coefficient of the rock, which is greater than or equal to, specifies general formula coefficient threshold, the infiltration is determined using following formula
Incidence relation between rate stress sensitive parameter and the bottom pressure：
η (Δ p)=A Δs p+B
Δ p=pi-pw
Wherein, (Δ p) indicates the permeability stress sensitive parameter to η；pwAnd piThe bottom pressure and described original is indicated respectively
Strata pressure；Δ p indicates that the original formation pressure subtracts the pressure difference obtained after the bottom pressure；A and B is constant；
When the general formula coefficient of the rock is less than the specified general formula coefficient threshold, the permeability is determined using following formula
Incidence relation between stress sensitive parameter and the bottom pressure：
η (Δ p)=C
Wherein, C is constant.
5. according to the method described in claim 1, it is characterized in that, the method be also provided with the purpose reservoir described
Gas properties data under original formation pressure；Wherein, the gas properties data are for characterizing gas in the purpose reservoir
Physical property characteristic；Determine the target gas well yield and the bottom pressure, first fracture permeabgility, the target gas
The second incidence relation between the production time of well, including：
It is wide based on the crack in the in-place permeability, the formation porosity, the formation thickness, the crack attribute data
Degree and fracture half-length and the gas properties data determine poor the target gas well yield and pseudopressure, pseudotime, institute
State the incidence relation between the first fracture permeabgility；Wherein, the pseudopressure difference indicates that the original formation pressure is corresponding quasi-
The difference of pressure and the corresponding pseudopressure of the bottom pressure；
Based on the gas properties data, the original formation pressure and the corresponding mean reservoir pressure of the target gas well, really
Fixed incidence relation between the pseudotime and the production time；
Based on the gas properties data and the original formation pressure, the corresponding quasi- pressure of the original formation pressure is determined respectively
Power and the incidence relation of the original formation pressure and the pass of the bottom pressure corresponding pseudopressure and the bottom pressure
Connection relationship；
Incidence relation according to the target gas well yield and pseudopressure between poor, pseudotime, first fracture permeabgility,
Incidence relation and the corresponding pseudopressure of the original formation pressure between the pseudotime and the production time with it is described
The incidence relation of the incidence relation of original formation pressure and the bottom pressure corresponding pseudopressure and the bottom pressure determines
Second incidence relation.
6. according to the method described in claim 5, it is characterized in that, using following formula determine the target gas well yield with
Pseudopressure is poor, the pseudotime, the incidence relation between first fracture permeabgility：
Wherein, q indicates the target gas well yield；m(pi)-m(pw) indicate that the pseudopressure is poor, m (pi) and m (pw) difference table
Show the corresponding pseudopressure of the original formation pressure and the corresponding pseudopressure of the bottom pressure；pwAnd piThe well is indicated respectively
Bottom pressure and the original formation pressure；nsIndicate to carry out the target gas well number of staged fracturing treated fracturing section
Amount, nfIndicate the crack quantity in a fracturing section, wfAnd xfThe fracture width in the crack attribute data is indicated respectively
And fracture half-length；Kf(pi) indicate first fracture permeabgility；KmIndicate that the in-place permeability, h indicate described ground thickness
Degree, φmIndicate the formation porosity, ηmiIndicate the stratum diffusion system under the original formation pressure of the purpose reservoir
Number；Bgi、μgiAnd cgiGas volume factor, gas viscosity and the gas compressibility factor in the gas properties data are indicated respectively；
taIndicate the pseudotime.
7. according to the method described in claim 5, it is characterized in that, determining the pseudotime and the production using following formula
Incidence relation between time：
Wherein, taIndicate the pseudotime；μgiIndicate the gas viscosity in the gas properties data,It indicates described original
Amendment gas compressibility factor under strata pressure, piIndicate the original formation pressure, μg[pavg(τ)] it indicates in the target gas
Gas viscosity under the corresponding mean reservoir pressure of well,It indicates corresponding average in the target gas well
Amendment gas compressibility factor under strata pressure, pavg(τ) indicates the corresponding mean reservoir pressure of the target gas well, described flat
Equal strata pressure is associated with the production time；τ indicates that time variable to be integrated, t indicate the production time.
8. according to the method described in claim 5, it is characterized in that, using the corresponding pseudopressure of bottom pressure described in following formula
With the incidence relation of the bottom pressure：
Wherein, m (pw) the corresponding pseudopressure of the bottom pressure is indicated respectively；μgiIndicate the gas in the gas properties data
Viscosity,Indicate the amendment Gaseous Z-factor under the original formation pressure, piIndicate the original formation pressure, ξ
Indicate pressure variations to be integrated, μg(ξ) indicates the amendment gas viscosity in the case where pressure value is the bottom pressure of ξ,Table
Show the amendment Gaseous Z-factor in the case where pressure value is the bottom pressure of ξ, pscIndicate standard atmospheric pressure, pwIndicate the shaft bottom pressure
Power.
9. according to the method described in claim 1, it is characterized in that, determining the corresponding bottom pressure of the target gas well and production
The correspondence of time, including：
According to first incidence relation and second incidence relation, determine that the target gas well yield is pressed with the shaft bottom
Incidence relation between power, the production time；
According to the target gas well yield and the incidence relation between the bottom pressure, the production time, determine respectively
Multiple specified production times correspond to the relation curve of multiple the target gas well yields and bottom pressure, and determine each described
The corresponding target bottom pressure of maximum point in relation curve；Wherein, the specified production time and the relation curve one
One corresponds to；
Processing is fitted to the specified production time and the target bottom pressure, obtains the corresponding well of the target gas well
The correspondence of bottom pressure and production time.
10. determining the device of the bottom pressure and the correspondence of time of shale gas well, which is characterized in that described device provides mesh
Work area in purpose reservoir layer attribute data, crack attribute data and rock mechanics data；Wherein, in the purpose work area
The target gas well of the purpose reservoir is met including boring；The crack attribute data is used to characterize the physical property characteristic in crack；Describedly
Layer attribute data includes the first fracture permeabgility, in-place permeability, formation porosity, formation thickness and original formation pressure；
First fracture permeabgility is for characterizing fracture permeabgility of the purpose reservoir under the original formation pressure；The dress
Set including：First incidence relation determining module, the second incidence relation determining module and target correspondence determining module；Wherein,
The first incidence relation determining module, for being based on the rock mechanics data and first fracture permeabgility, really
Determine the first incidence relation between corresponding second fracture permeabgility of the target gas well and bottom pressure；Wherein, described second
Fracture permeabgility is for characterizing fracture permeabgility of the purpose reservoir under the bottom pressure；
The second incidence relation determining module, for being based on the in-place permeability, the formation porosity and the stratum
Thickness and the crack attribute data determine that the target gas well yield is oozed with the bottom pressure, first crack
Saturating rate, the target gas well production time between the second incidence relation；
The target correspondence determining module, for according to first incidence relation and second incidence relation, determining
The correspondence of the target gas well corresponding bottom pressure and production time.
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