CN105134179B - A kind of computational methods of natural gas well wellbore pressure and the distributed data of temperature - Google Patents

A kind of computational methods of natural gas well wellbore pressure and the distributed data of temperature Download PDF

Info

Publication number
CN105134179B
CN105134179B CN201510520092.0A CN201510520092A CN105134179B CN 105134179 B CN105134179 B CN 105134179B CN 201510520092 A CN201510520092 A CN 201510520092A CN 105134179 B CN105134179 B CN 105134179B
Authority
CN
China
Prior art keywords
mrow
msub
wellbore section
natural gas
mfrac
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Active
Application number
CN201510520092.0A
Other languages
Chinese (zh)
Other versions
CN105134179A (en
Inventor
马振
贺梦琦
曲绍刚
孙振宇
王智博
杨宝春
柏明星
王玲
赵吉成
吴晓明
杨昕
马薇
马威
王昕�
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
China Petroleum and Natural Gas Co Ltd
Original Assignee
China Petroleum and Natural Gas Co Ltd
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by China Petroleum and Natural Gas Co Ltd filed Critical China Petroleum and Natural Gas Co Ltd
Priority to CN201510520092.0A priority Critical patent/CN105134179B/en
Publication of CN105134179A publication Critical patent/CN105134179A/en
Application granted granted Critical
Publication of CN105134179B publication Critical patent/CN105134179B/en
Active legal-status Critical Current
Anticipated expiration legal-status Critical

Links

Landscapes

  • Measuring Temperature Or Quantity Of Heat (AREA)
  • Engine Equipment That Uses Special Cycles (AREA)

Abstract

The invention provides the computational methods of a kind of natural gas well wellbore pressure and the distributed data of temperature, are related to natural gas filling and adopt technical field, method includes：The associated parameter data of natural gas well pit shaft is obtained under a preparatory condition；The material calculation of the pit shaft pre-set is obtained, and natural gas well pit shaft is divided into multiple wellbore sections；According to associated parameter data, as initial calculation point, to calculate the pressure value in each wellbore section exit and the temperature value in each wellbore section exit successively at natural gas well pit shaft well head；The pressure distribution of natural gas well pit shaft is determined according to the pressure value in each wellbore section exit, and the Temperature Distribution of natural gas well pit shaft is determined according to the temperature value in each wellbore section exit.The present invention will intercouple between pressure and temperature, and by the way of gradual iteration, the pressure and temperature data of acquisition are more accurate.Solve the problems, such as that theory analysis means of the prior art are also difficult to the distribution for accurately determining natural gas well wellbore pressure and temperature.

Description

A kind of computational methods of natural gas well wellbore pressure and the distributed data of temperature
Technical field
The present invention relates to natural gas filling to adopt technical field, more particularly to the distribution of a kind of natural gas well wellbore pressure and temperature The computational methods of data.
Background technology
At present, in natural gas filling adopts technical field, the analysis for natural gas well wellbore pressure and temperature can be direct Have influence on the optimization of productivity evaluation of gas well, production system dynamic analysis and production facility etc..
The approach of the distributed data of the current pressure and temperature for obtaining natural gas well pit shaft is generally：1. arrange in the wellbore A number of pressure gauge and thermometer, to obtain the pressure and temperature of whole pit shaft distribution feelings by pressure gauge and thermometer Condition；2. only surveying shaft bottom or well head pressure, temperature, pressure, the Temperature Distribution of whole pit shaft are predicted using theoretical analysis method.So And for some scaled high-pressure natural gas wells, it is sometimes difficult to carry out the operation of lower pressure gauge, thermometer.Therefore, currently typically adopt Pressure, the Temperature Distribution of whole pit shaft are predicted with theoretical analysis method.At present, the method for natural gas well wellbore pressure temperature computation It is general only to study the Temperature Distribution of gas in pit shaft using pressure is reasonably apart from, or segmentation as entirety or is passed through using pit shaft The method of temperature-averaging, the iterative calculation formula of bottom pressure is derived, it is determined that the temperature and pressure of pit shaft.
But current theory analysis means are also difficult to the distribution for accurately determining natural gas well wellbore pressure and temperature, mesh It is preceding also without it is a kind of being capable of fast and accurately computational methods of natural gas well wellbore pressure and the distributed data of temperature.
The content of the invention
The embodiment of the present invention provides the computational methods of a kind of natural gas well wellbore pressure and the distributed data of temperature, to solve Theory analysis means of the prior art are also difficult to the distribution for accurately determining natural gas well wellbore pressure and temperature, do not have also at present Have it is a kind of can fast and accurately the computational methods of natural gas well wellbore pressure and the distributed data of temperature the problem of.
In order to achieve the above object, the present invention adopts the following technical scheme that：
A kind of computational methods of natural gas well wellbore pressure and the distributed data of temperature, including：
The associated parameter data of the natural gas well pit shaft is obtained under a preparatory condition；
The material calculation of the pit shaft pre-set is obtained, and the natural gas well pit shaft is divided into multiple wellbore sections；
According to the associated parameter data, as initial calculation point, to calculate each pit shaft successively at natural gas well pit shaft well head The section pressure value in exit and the temperature value in each wellbore section exit；
The pressure distribution of the natural gas well pit shaft is determined according to the pressure value in each wellbore section exit, and according to institute The temperature value for stating each wellbore section exit determines the Temperature Distribution of the natural gas well pit shaft.
Specifically, the associated parameter data, including：
Pressure value P at natural gas well pit shaft well head1；Temperature value T at natural gas well pit shaft well head1；Natural gas well pit shaft Geothermal gradient gT；Gas flow Q in natural gas well pit shaftsc；Pipe aperture D；Gas relative density γ；The ground of each wellbore section Layer temperature Te；Gas injection temperature T in pit shaftFirmly；Annular fluid thermal conductivity factor Kha；Oil pipe outer radius rto；Sleeve pipe inside radius rci；Oil Tube wall temperature Tto；Gas injection time tD；Oil pipe inside radius rti；The Forced Convection Heat Transfer coefficient h of tube inner wall gasf；Oil pipe is led Hot COEFFICIENT Ktub；Sleeve pipe outer radius rco；Sleeve pipe thermal conductivity factor Kcas；Well radius rh；The formation thermal conductivity K of each wellbore sectione；Gas Body compressibility factor Z；Gas specific heat at constant pressure holds Cpg；Joule-Thomson coefficient CJ；Natural gas well total depth H.
In addition, it is described according to the associated parameter data, as initial calculation point, to be counted successively at natural gas well pit shaft well head The pressure value in each wellbore section exit and the temperature value in each wellbore section exit are calculated, including：
Determine the pressure value P of i-th of wellbore section porchi' and i-th wellbore section porch temperature value Ti'；
Wherein, Pi'=Pi, Ti'=Ti, i >=1；PiFor the pressure value in the i-th -1 wellbore section exit；TiFor the i-th -1 well The temperature value in cylinder section exit；As i=1, P1'=P1, T1'=T1；P1For the pressure value at the natural gas well pit shaft well head； T1For the temperature value at the natural gas well pit shaft well head；
The preset pressure value P in i-th of wellbore section exit is seti+1' and i-th wellbore section exit preset temperature value Ti+1'；
Wherein,Dl is the material calculation of the pit shaft；
Determine the average pressure value of i-th of wellbore sectionWith the average temperature value of i-th of wellbore section
Wherein,
Further, it is described according to the associated parameter data, using at natural gas well pit shaft well head as initial calculation point, according to The temperature value of the secondary pressure value and each wellbore section exit for calculating each wellbore section exit, in addition to：
Determine the first coefficient I of i-th of wellbore sectioniWith the second coefficient Ii+1：
Further, it is described according to the associated parameter data, using at natural gas well pit shaft well head as initial calculation point, according to The temperature value of the secondary pressure value and each wellbore section exit for calculating each wellbore section exit, in addition to：
Determine the 3rd coefficient C of natural gas well pit shaft1With the 4th coefficient C2：
C2=3484.48 γ.
Further, it is described according to the associated parameter data, using at natural gas well pit shaft well head as initial calculation point, according to The temperature value of the secondary pressure value and each wellbore section exit for calculating each wellbore section exit, in addition to：
According to formula：
Calculate the calculating pressure value P in i-th of wellbore section exiti+1；Wherein, g is acceleration of gravity；θ is i-th of well The angle of cylinder section and horizontal direction；F is the coefficient of frictional resistance of gas and tube inner wall in pit shaft.
Further, it is described according to the associated parameter data, using at natural gas well pit shaft well head as initial calculation point, according to The temperature value of the secondary pressure value and each wellbore section exit for calculating each wellbore section exit, in addition to：
According to formula：
Calculate the annular space mean temperature T of i-th of wellbore sectionan；Wherein, TFirmlyFor the gas injection temperature in pit shaft；TeFor i-th of well The formation temperature of cylinder section；
Obtain the formation temperature T of i-th of wellbore sectioneUnder annular fluid density pan, viscosity UanAnd thermal capacitance Can。
Further, it is described according to the associated parameter data, using at natural gas well pit shaft well head as initial calculation point, according to The temperature value of the secondary pressure value and each wellbore section exit for calculating each wellbore section exit, in addition to：
Calculate annular space free convection heat transfer coefficient hc：
Wherein, Grashof numbers：Prandtl numbers：
Further, it is described according to the associated parameter data, using at natural gas well pit shaft well head as initial calculation point, according to The temperature value of the secondary pressure value and each wellbore section exit for calculating each wellbore section exit, in addition to：
Calculate annular space radiation heat transfer coefficient hr：
Wherein, T*=TFirmly+273.15；Te *=Te+273.15；FtciFor oil-pipe external wall surface To internal surface of sleeve pipe surface emissivity coefficient of efficiency；εoFor oil-pipe external wall blackness；εciFor internal surface of sleeve pipe blackness；δ is Stefan- Boltzmann constants, δ=2.189 × 10-8W/(m2·K)。
Further, it is described according to the associated parameter data, using at natural gas well pit shaft well head as initial calculation point, according to The temperature value of the secondary pressure value and each wellbore section exit for calculating each wellbore section exit, in addition to：
According to formula：
Determine Ramey non dimensional time function f (t).
In addition, it is described according to the associated parameter data, as initial calculation point, to be counted successively at natural gas well pit shaft well head The pressure value in each wellbore section exit and the temperature value in each wellbore section exit are calculated, in addition to：
According to formula：
Determine oil pipe to total thermal conductivity factor U on stratumto。
Further, it is described according to the associated parameter data, using at natural gas well pit shaft well head as initial calculation point, according to The temperature value of the secondary pressure value and each wellbore section exit for calculating each wellbore section exit, in addition to：
Determine the pressure difference value dP of i-th of wellbore section exit and porchi：
dPi=Pi+1-Pi；
Determine the gas mean flow rate of i-th of wellbore sectionWith the gas flow rate in i-th of wellbore section exit and porch Difference dvi：
dvi=vi+1-vi；
Wherein,
In addition, it is described according to the associated parameter data, as initial calculation point, to be counted successively at natural gas well pit shaft well head The pressure value in each wellbore section exit and the temperature value in each wellbore section exit are calculated, in addition to：
According to formula：
Calculate the calculating temperature value T in i-th of wellbore section exiti+1；
Wherein, Tei+1For the formation temperature in i-th of wellbore section exit；TeiFor the stratum temperature of i-th of wellbore section porch Degree；KeFor the formation thermal conductivity of i-th of wellbore section；GgFor gas mass velocity.
In addition, it is described according to the associated parameter data, as initial calculation point, to be counted successively at natural gas well pit shaft well head The pressure value in each wellbore section exit and the temperature value in each wellbore section exit are calculated, in addition to：
Judge | Ti+1-Ti+1' | whether less than one first predetermined threshold value, and | Pi+1-Pi+1' | it is whether default less than one second Threshold value；
If | Ti+1-Ti+1' | less than one first predetermined threshold value, and | Pi+1-Pi+1' | less than one second predetermined threshold value, determine institute State the calculating pressure value P in i-th of wellbore section exiti+1With the calculating temperature value T in i-th of wellbore section exiti+1Accurately； And by Pi+1As the pressure value of i+1 wellbore section porch, by Ti+1As the temperature value of i+1 wellbore section porch, Continue to calculate the calculating pressure value in i+1 wellbore section exit and calculate temperature value；
If | Ti+1-Ti+1' | more than or equal to first predetermined threshold value, or | Pi+1-Pi+1' | it is pre- more than or equal to described second If threshold value, then redefine Pi+1' it is equal to Pi+1, and Ti+1' it is equal to Ti+1, and recalculate the average pressure value of i-th of wellbore sectionWith the average temperature value of i-th of wellbore section
Specifically, it is determined that the calculating pressure value P in i-th of wellbore section exiti+1Go out with i-th of wellbore section Calculating temperature value T at mouthfuli+1After accurate, methods described also includes：
Count the material calculation and l of currently calculated each pit shaft；
If l >=H, it is determined that the pressure value in each wellbore section exit in the natural gas well pit shaft and the outlet of each wellbore section The temperature value at place is calculated and finished.
The computational methods of a kind of natural gas well wellbore pressure provided in an embodiment of the present invention and the distributed data of temperature, pass through Natural gas well pit shaft is divided into multiple wellbore sections, so as to the associated parameter data according to natural gas well pit shaft, with the natural gas well It is initial calculation point at pit shaft well head, calculates the pressure value in each wellbore section exit and the temperature in each wellbore section exit successively Value；And then the pressure distribution of natural gas well pit shaft is determined according to the pressure value in each wellbore section exit, and gone out according to each wellbore section Temperature value at mouthful determines the Temperature Distribution of natural gas well pit shaft.It is determined that the pressure in each wellbore section exit in the embodiment of the present invention During the temperature value in force value and each wellbore section exit, it will intercouple between pressure and temperature, by the way of gradual iteration, obtain The pressure and temperature data obtained are more accurate.Solve theory analysis means of the prior art to be also difficult to accurately determine naturally The problem of distribution of the pressure of well bore in gas well and temperature.
Brief description of the drawings
In order to illustrate more clearly about the embodiment of the present invention or technical scheme of the prior art, below will be to embodiment or existing There is the required accompanying drawing used in technology description to be briefly described, it should be apparent that, drawings in the following description are only this Some embodiments of invention, for those of ordinary skill in the art, without having to pay creative labor, may be used also To obtain other accompanying drawings according to these accompanying drawings.
Fig. 1 is the computational methods of a kind of natural gas well wellbore pressure provided in an embodiment of the present invention and the distributed data of temperature Flow chart one；
Fig. 2 is natural gas well shaft structure schematic diagram provided in an embodiment of the present invention；
Fig. 3 is the computational methods of a kind of natural gas well wellbore pressure provided in an embodiment of the present invention and the distributed data of temperature Flowchart 2.
Embodiment
Below in conjunction with the accompanying drawing in the embodiment of the present invention, the technical scheme in the embodiment of the present invention is carried out clear, complete Site preparation describes, it is clear that described embodiment is only part of the embodiment of the present invention, rather than whole embodiments.It is based on Embodiment in the present invention, those of ordinary skill in the art are obtained every other under the premise of creative work is not made Embodiment, belong to the scope of protection of the invention.
As shown in figure 1, the meter of a kind of natural gas well wellbore pressure provided in an embodiment of the present invention and the distributed data of temperature Calculation method, including：
Step 101, under a preparatory condition obtain natural gas well pit shaft associated parameter data.
The material calculation for the pit shaft that step 102, acquisition are pre-set, and natural gas well pit shaft is divided into multiple pit shafts Section.
Step 103, according to associated parameter data, as initial calculation point, to be calculated successively each at natural gas well pit shaft well head The pressure value in wellbore section exit and the temperature value in each wellbore section exit.
Step 104, the pressure distribution for determining according to the pressure value in each wellbore section exit natural gas well pit shaft, and according to each The temperature value in wellbore section exit determines the Temperature Distribution of natural gas well pit shaft.
The computational methods of a kind of natural gas well wellbore pressure provided in an embodiment of the present invention and the distributed data of temperature, pass through Natural gas well pit shaft is divided into multiple wellbore sections, so as to the associated parameter data according to natural gas well pit shaft, with the natural gas well It is initial calculation point at pit shaft well head, calculates the pressure value in each wellbore section exit and the temperature in each wellbore section exit successively Value；And then the pressure distribution of natural gas well pit shaft is determined according to the pressure value in each wellbore section exit, and gone out according to each wellbore section Temperature value at mouthful determines the Temperature Distribution of natural gas well pit shaft.It is determined that the pressure in each wellbore section exit in the embodiment of the present invention During the temperature value in force value and each wellbore section exit, it will intercouple between pressure and temperature, by the way of gradual iteration, obtain The pressure and temperature data obtained are more accurate.Solve theory analysis means of the prior art to be also difficult to accurately determine naturally The problem of distribution of the pressure of well bore in gas well and temperature.
What deserves to be explained is current wellbore pressure, temperature computation method are separated, seldom consider therebetween Influence each other.And corresponding mathematical modeling is established with the coupling calculation of temperature using pressure in the present invention, and to working as Preceding Cullender-Smith methods are improved, and can accurately and fast calculate any flow condition, any time, Yan Jing The pressure and temp distribution of cylinder.
What deserves to be explained is above-mentioned preparatory condition can be：
(1) for the fluid flow state in pit shaft to stablize one-way flow, fluid is gas single-phase flow.
(2) heat transfer is steady heat transfer in pit shaft.
(3) stratum heat transfer is unsteady heat transfer, and obeys Ramey non dimensional time function.
(4) casing programme is as shown in Figure 2：Include oil pipe-oil jacket annular space-sleeve pipe-cement sheath-stratum respectively.
In fig. 2, TfFor the gas injection temperature in oil pipe (i.e. pit shaft), TtiFor tube inner wall temperature, TtoFor oil-pipe external wall temperature Degree, TciFor internal surface of sleeve pipe temperature, TcoFor sleeve outer wall temperature, ThFor cement sheath temperature.rtoFor oil pipe outer radius；rciFor sleeve pipe Inside radius；rtiFor oil pipe inside radius；rcoFor sleeve pipe outer radius；rhFor well radius.
(5) heat loss in pit shaft and surrounding formation is radial direction, does not consider the heat transfer along well depth direction.
(6) formation temperature presses linear change, and known geothermal gradient.
(7) oil pipe and sleeve pipe are concentric.
In addition, the associated parameter data of natural gas well pit shaft, can include the pressure value P at natural gas well pit shaft well head1； Temperature value T at natural gas well pit shaft well head1；The geothermal gradient g of natural gas well pit shaftT；Gas flow in natural gas well pit shaft Qsc；Pipe aperture D；Gas relative density γ；The formation temperature T of each wellbore sectione；Gas injection temperature T in pit shaftFirmly；Annular fluid Thermal conductivity factor Kha；Oil pipe outer radius rto；Sleeve pipe inside radius rci；Oil-pipe external wall temperature Tto；Gas injection time tD；Oil pipe inside radius rti； The Forced Convection Heat Transfer coefficient h of tube inner wall gasf；Oil pipe thermal conductivity factor Ktub；Sleeve pipe outer radius rco；Sleeve pipe thermal conductivity factor Kcas；Well radius rh；The formation thermal conductivity K of each wellbore sectione；Gas Compression Factor Z；Gas specific heat at constant pressure holds Cpg；Joule- Thomson coefficient CJ；Natural gas well total depth H etc., but it is not only limited to this.
The present invention is better understood from for the ease of those skilled in the art, a more specifically embodiment is set forth below, As shown in figure 3, the computational methods of a kind of natural gas well wellbore pressure provided in an embodiment of the present invention and the distributed data of temperature, bag Include：
Step 201, under a preparatory condition obtain natural gas well pit shaft associated parameter data.
The embodiment of the associated parameter data and the particular content of preparatory condition as corresponding to Fig. 1, here is omitted.
The material calculation for the pit shaft that step 202, acquisition are pre-set, and natural gas well pit shaft is divided into multiple pit shafts Section.
Wherein, the material calculation of the pit shaft pre-set is dl, and natural gas well pit shaft total depth is H.
Step 203, determine to be initial calculation point at natural gas well pit shaft well head.
For initial calculation point, dl's and l be 0, and i initial value is 1, i.e., first calculates the 1st wellbore section exit Pressure value and temperature value, then the pressure value and temperature value in each wellbore section exit are calculated successively.
Step 204, the pressure value P for determining i-th of wellbore section porchi' and i-th wellbore section porch temperature value Ti'。
Wherein, Pi'=Pi, Ti'=Ti, i >=1；PiFor the pressure value in the i-th -1 wellbore section exit；TiFor the i-th -1 well The temperature value in cylinder section exit；As i=1, P1'=P1, T1'=T1；P1For the pressure value at natural gas well pit shaft well head；T1For Temperature value at natural gas well pit shaft well head.
Step 205, the preset pressure value P that i-th of wellbore section exit is seti+1' and i-th wellbore section exit is pre- If temperature value Ti+1'。
Wherein,Dl is the material calculation of pit shaft.
Step 206, the average pressure value for determining i-th of wellbore sectionWith the average temperature value of i-th of wellbore section
Wherein,
Step 207, the first coefficient I for determining i-th of wellbore sectioniWith the second coefficient Ii+1。
Wherein,
Step 208, the 3rd coefficient C for determining natural gas well pit shaft1With the 4th coefficient C2。
Wherein,C2=3484.48 γ.
Step 209, the calculating pressure value P for calculating i-th of wellbore section exiti+1。
Herein, specifically can be according to formula：
Calculate the calculating pressure value P in i-th of wellbore section exiti+1；Wherein, g is acceleration of gravity；θ is i-th of well The angle of cylinder section and horizontal direction；F is the coefficient of frictional resistance of gas and tube inner wall in pit shaft.
Step 210, the annular space mean temperature T for calculating i-th of wellbore sectionan, and obtain the formation temperature T of i-th of wellbore sectione Under annular fluid density pan, viscosity UanAnd thermal capacitance Can。
Herein, specifically can be according to formula：
Calculate the annular space mean temperature T of i-th of wellbore sectionan；Wherein, TFirmlyFor the gas injection temperature in pit shaft；TeFor i-th of well The formation temperature of cylinder section.
Step 211, calculate annular space free convection heat transfer coefficient hc。
Wherein, Grashof numbers：Prandtl numbers：
Step 212, calculate annular space radiation heat transfer coefficient hr。
Wherein, T*=TFirmly+273.15；Te *=Te+273.15；FtciFor oil-pipe external wall surface To internal surface of sleeve pipe surface emissivity coefficient of efficiency；εoFor oil-pipe external wall blackness；εciFor internal surface of sleeve pipe blackness；δ is Stefan- Boltzmann constants, δ=2.189 × 10-8W/(m2·K)。
Step 213, determine Ramey non dimensional time function f (t).
Wherein, formula can specifically be passed through：
To determine the Ramey non dimensional time function f (t).
Step 214, determine oil pipe to total thermal conductivity factor U on stratumto。
Its specific mode can be determined by equation below：
Step 215, the pressure difference value dP for determining i-th of wellbore section exit and porchi。
Wherein：
dPi=Pi+1-Pi；
Step 216, the gas mean flow rate for determining i-th of wellbore sectionWith i-th of wellbore section exit and porch Gas flow rate difference dvi。
Wherein：
dvi=vi+1-vi；
Wherein,
Step 217, the calculating temperature value T for calculating i-th of wellbore section exiti+1。
Its specific mode can determine according to equation below：
Wherein, Tei+1For the formation temperature in i-th of wellbore section exit；TeiFor the stratum temperature of i-th of wellbore section porch Degree；KeFor the formation thermal conductivity of i-th of wellbore section；GgFor gas mass velocity.
Step 218, judge | Ti+1-Ti+1' | whether less than one first predetermined threshold value, and | Pi+1-Pi+1' | whether less than one Second predetermined threshold value.
If | Ti+1-Ti+1' | less than one first predetermined threshold value, and | Pi+1-Pi+1' | less than one second predetermined threshold value, then perform Step 219.
If | Ti+1-Ti+1' | more than or equal to the first predetermined threshold value, or | Pi+1-Pi+1' | more than or equal to the second predetermined threshold value, Then perform step 221.
Step 219, the calculating pressure value P for determining i-th of wellbore section exiti+1With the calculating in i-th of wellbore section exit Temperature value Ti+1Accurately, and by Pi+1As the pressure value of i+1 wellbore section porch, by Ti+1Enter as i+1 wellbore section Temperature value at mouthful.Step 220 is performed afterwards, or is returned and performed step 205.
The material calculation and l of the currently calculated each pit shaft of step 220, statistics, if l >=H, it is determined that natural gas well well The pressure value in each wellbore section exit in cylinder and the temperature value in each wellbore section exit, which calculate, to be finished.
Step 221, redefine Pi+1' it is equal to Pi+1, and Ti+1' it is equal to Ti+1.Afterwards, return and perform step 206.
The computational methods of a kind of natural gas well wellbore pressure provided in an embodiment of the present invention and the distributed data of temperature, pass through Natural gas well pit shaft is divided into multiple wellbore sections, so as to the associated parameter data according to natural gas well pit shaft, with the natural gas well It is initial calculation point at pit shaft well head, calculates the pressure value in each wellbore section exit and the temperature in each wellbore section exit successively Value；And then the pressure distribution of natural gas well pit shaft is determined according to the pressure value in each wellbore section exit, and gone out according to each wellbore section Temperature value at mouthful determines the Temperature Distribution of natural gas well pit shaft.It is determined that the pressure in each wellbore section exit in the embodiment of the present invention During the temperature value in force value and each wellbore section exit, it will intercouple between pressure and temperature, by the way of gradual iteration, obtain The pressure and temperature data obtained are more accurate.Solve theory analysis means of the prior art to be also difficult to accurately determine naturally The problem of distribution of the pressure of well bore in gas well and temperature.
Apply specific embodiment in the present invention to be set forth the principle and embodiment of the present invention, above example Explanation be only intended to help understand the present invention method and its core concept；Meanwhile for those of ordinary skill in the art, According to the thought of the present invention, there will be changes in specific embodiments and applications, in summary, in this specification Appearance should not be construed as limiting the invention.

Claims (13)

  1. A kind of 1. computational methods of natural gas well wellbore pressure and the distributed data of temperature, it is characterised in that including：
    The associated parameter data of the natural gas well pit shaft is obtained under a preparatory condition；
    The material calculation of the pit shaft pre-set is obtained, and the natural gas well pit shaft is divided into multiple wellbore sections；
    According to the associated parameter data, as initial calculation point, to calculate each wellbore section successively at natural gas well pit shaft well head and go out The temperature value of pressure value and each wellbore section exit at mouthful；
    The pressure distribution of the natural gas well pit shaft is determined according to the pressure value in each wellbore section exit, and according to described each The temperature value in wellbore section exit determines the Temperature Distribution of the natural gas well pit shaft；
    The associated parameter data, including：
    Pressure value P at natural gas well pit shaft well head1；Temperature value T at natural gas well pit shaft well head1；The ground of natural gas well pit shaft Warm gradient gT；Gas flow Q in natural gas well pit shaftsc；Pipe aperture D；Gas relative density γ；The stratum temperature of each wellbore section Spend Te；Gas injection temperature T in pit shaftFirmly；Annular fluid thermal conductivity factor Kha；Oil pipe outer radius rto；Sleeve pipe inside radius rci；Outside oil pipe Wall temperature Tto；Gas injection time tD；Oil pipe inside radius rti；The Forced Convection Heat Transfer coefficient h of tube inner wall gasf；Oil pipe heat conduction system Number Ktub；Sleeve pipe outer radius rco；Sleeve pipe thermal conductivity factor Kcas；Well radius rh；The formation thermal conductivity K of each wellbore sectione；Gas pressure Contracting factor Z；Gas specific heat at constant pressure holds Cpg；Joule-Thomson coefficient CJ；Natural gas well total depth H；
    It is described according to the associated parameter data, as initial calculation point, to calculate each pit shaft successively at natural gas well pit shaft well head The section pressure value in exit and the temperature value in each wellbore section exit, including：
    Determine the pressure value P of i-th of wellbore section porchi' and i-th wellbore section porch temperature value Ti'；
    Wherein, Pi'=Pi, Ti'=Ti, i >=1；PiFor the pressure value in the i-th -1 wellbore section exit；TiFor the i-th -1 wellbore section The temperature value in exit；As i=1, P1'=P1, T1'=T1；P1For the pressure value at the natural gas well pit shaft well head；T1For Temperature value at the natural gas well pit shaft well head；
    The preset pressure value P in i-th of wellbore section exit is seti+1' and i-th wellbore section exit preset temperature value Ti+1'；
    Wherein,Dl is the material calculation of the pit shaft；
    Determine the average pressure value of i-th of wellbore sectionWith the average temperature value of i-th of wellbore section
    Wherein,
  2. 2. the computational methods of natural gas well wellbore pressure according to claim 1 and the distributed data of temperature, its feature exist In, it is described according to the associated parameter data, as initial calculation point, to calculate each wellbore section successively at natural gas well pit shaft well head The pressure value in exit and the temperature value in each wellbore section exit, in addition to：
    Determine the first coefficient I of i-th of wellbore sectioniWith the second coefficient Ii+1：
    <mfenced open = "" close = ""> <mtable> <mtr> <mtd> <mrow> <msub> <mi>I</mi> <mi>i</mi> </msub> <mo>=</mo> <mfrac> <mrow> <msup> <msub> <mi>ZT</mi> <mi>i</mi> </msub> <mo>&amp;prime;</mo> </msup> </mrow> <mrow> <msup> <msub> <mi>P</mi> <mi>i</mi> </msub> <mo>&amp;prime;</mo> </msup> </mrow> </mfrac> <mo>;</mo> </mrow> </mtd> <mtd> <mrow> <msub> <mi>I</mi> <mrow> <mi>i</mi> <mo>+</mo> <mn>1</mn> </mrow> </msub> <mo>=</mo> <mfrac> <mrow> <msup> <msub> <mi>ZT</mi> <mrow> <mi>i</mi> <mo>+</mo> <mn>1</mn> </mrow> </msub> <mo>&amp;prime;</mo> </msup> </mrow> <mrow> <msup> <msub> <mi>P</mi> <mrow> <mi>i</mi> <mo>+</mo> <mn>1</mn> </mrow> </msub> <mo>&amp;prime;</mo> </msup> </mrow> </mfrac> <mo>.</mo> </mrow> </mtd> </mtr> </mtable> </mfenced>
  3. 3. the computational methods of natural gas well wellbore pressure according to claim 2 and the distributed data of temperature, its feature exist In, it is described according to the associated parameter data, as initial calculation point, to calculate each wellbore section successively at natural gas well pit shaft well head The pressure value in exit and the temperature value in each wellbore section exit, in addition to：
    Determine the 3rd coefficient C of natural gas well pit shaft1With the 4th coefficient C2：
    <mrow> <msub> <mi>C</mi> <mn>1</mn> </msub> <mo>=</mo> <mn>5</mn> <mo>&amp;times;</mo> <msup> <mn>10</mn> <mrow> <mo>-</mo> <mn>9</mn> </mrow> </msup> <mo>&amp;times;</mo> <mfrac> <msub> <mi>Q</mi> <mrow> <mi>s</mi> <mi>c</mi> </mrow> </msub> <msup> <mi>D</mi> <mn>2</mn> </msup> </mfrac> <mo>;</mo> </mrow>
    C2=3484.48 γ.
  4. 4. the computational methods of natural gas well wellbore pressure according to claim 3 and the distributed data of temperature, its feature exist In, it is described according to the associated parameter data, as initial calculation point, to calculate each wellbore section successively at natural gas well pit shaft well head The pressure value in exit and the temperature value in each wellbore section exit, in addition to：
    According to formula：
    <mrow> <msub> <mi>P</mi> <mrow> <mi>i</mi> <mo>+</mo> <mn>1</mn> </mrow> </msub> <mo>=</mo> <msub> <mi>P</mi> <mi>i</mi> </msub> <mo>-</mo> <mo>&amp;lsqb;</mo> <msubsup> <mi>C</mi> <mn>1</mn> <mn>2</mn> </msubsup> <msub> <mi>C</mi> <mn>2</mn> </msub> <mrow> <mo>(</mo> <msub> <mi>I</mi> <mrow> <mi>i</mi> <mo>+</mo> <mn>1</mn> </mrow> </msub> <mo>-</mo> <msub> <mi>I</mi> <mi>i</mi> </msub> <mo>)</mo> </mrow> <mo>+</mo> <mfrac> <mrow> <msub> <mi>C</mi> <mn>2</mn> </msub> <mi>g</mi> <mi>s</mi> <mi>i</mi> <mi>n</mi> <mi>&amp;theta;</mi> </mrow> <mn>2</mn> </mfrac> <mrow> <mo>(</mo> <mfrac> <mrow> <msub> <mi>I</mi> <mi>i</mi> </msub> <mo>+</mo> <msub> <mi>I</mi> <mrow> <mi>i</mi> <mo>+</mo> <mn>1</mn> </mrow> </msub> </mrow> <mn>2</mn> </mfrac> <mo>)</mo> </mrow> <mi>d</mi> <mi>l</mi> <mo>+</mo> <mfrac> <mrow> <msubsup> <mi>fC</mi> <mn>1</mn> <mn>2</mn> </msubsup> <msub> <mi>C</mi> <mn>2</mn> </msub> </mrow> <mrow> <mn>2</mn> <mi>D</mi> </mrow> </mfrac> <mo>&amp;times;</mo> <mfrac> <mrow> <msub> <mi>I</mi> <mi>i</mi> </msub> <mo>+</mo> <msub> <mi>I</mi> <mrow> <mi>i</mi> <mo>+</mo> <mn>1</mn> </mrow> </msub> </mrow> <mn>2</mn> </mfrac> <mi>d</mi> <mi>l</mi> <mo>&amp;rsqb;</mo> <mo>&amp;times;</mo> <msup> <mn>10</mn> <mrow> <mo>-</mo> <mn>6</mn> </mrow> </msup> </mrow>
    Calculate the calculating pressure value P in i-th of wellbore section exiti+1；Wherein, g is acceleration of gravity；θ is i-th of wellbore section With the angle of horizontal direction；F is the coefficient of frictional resistance of gas and tube inner wall in pit shaft.
  5. 5. the computational methods of natural gas well wellbore pressure according to claim 4 and the distributed data of temperature, its feature exist In, it is described according to the associated parameter data, as initial calculation point, to calculate each wellbore section successively at natural gas well pit shaft well head The pressure value in exit and the temperature value in each wellbore section exit, in addition to：
    According to formula：
    Calculate the annular space mean temperature T of i-th of wellbore sectionan；Wherein, TFirmlyFor the gas injection temperature in pit shaft；TeFor i-th of wellbore section Formation temperature；
    Obtain the formation temperature T of i-th of wellbore sectioneUnder annular fluid density pan, viscosity UanAnd thermal capacitance Can。
  6. 6. the computational methods of natural gas well wellbore pressure according to claim 5 and the distributed data of temperature, its feature exist In, it is described according to the associated parameter data, as initial calculation point, to calculate each wellbore section successively at natural gas well pit shaft well head The pressure value in exit and the temperature value in each wellbore section exit, in addition to：
    Calculate annular space free convection heat transfer coefficient hc：
    <mrow> <msub> <mi>h</mi> <mi>c</mi> </msub> <mo>=</mo> <mfrac> <mrow> <mn>0.049</mn> <msup> <mrow> <mo>(</mo> <msub> <mi>G</mi> <mi>r</mi> </msub> <msub> <mi>P</mi> <mi>r</mi> </msub> <mo>)</mo> </mrow> <mn>0.33</mn> </msup> <msup> <msub> <mi>P</mi> <mi>r</mi> </msub> <mn>0.074</mn> </msup> <msub> <mi>K</mi> <mrow> <mi>h</mi> <mi>a</mi> </mrow> </msub> </mrow> <mrow> <msub> <mi>r</mi> <mrow> <mi>t</mi> <mi>o</mi> </mrow> </msub> <mi>l</mi> <mi>n</mi> <mfrac> <msub> <mi>r</mi> <mrow> <mi>c</mi> <mi>i</mi> </mrow> </msub> <msub> <mi>r</mi> <mrow> <mi>t</mi> <mi>o</mi> </mrow> </msub> </mfrac> </mrow> </mfrac> </mrow>
    Wherein, Grashof numbers：Prandtl numbers：
  7. 7. the computational methods of natural gas well wellbore pressure according to claim 6 and the distributed data of temperature, its feature exist In, it is described according to the associated parameter data, as initial calculation point, to calculate each wellbore section successively at natural gas well pit shaft well head The pressure value in exit and the temperature value in each wellbore section exit, in addition to：
    Calculate annular space radiation heat transfer coefficient hr：
    <mrow> <msub> <mi>h</mi> <mi>r</mi> </msub> <mo>=</mo> <msub> <mi>&amp;delta;F</mi> <mrow> <mi>t</mi> <mi>c</mi> <mi>i</mi> </mrow> </msub> <mrow> <mo>(</mo> <msup> <mi>T</mi> <mrow> <mo>*</mo> <mn>2</mn> </mrow> </msup> <mo>+</mo> <msubsup> <mi>T</mi> <mi>e</mi> <mrow> <mo>*</mo> <mn>2</mn> </mrow> </msubsup> <mo>)</mo> </mrow> <mo>+</mo> <mrow> <mo>(</mo> <msup> <mi>T</mi> <mo>*</mo> </msup> <mo>+</mo> <msubsup> <mi>T</mi> <mi>e</mi> <mo>*</mo> </msubsup> <mo>)</mo> </mrow> </mrow>
    Wherein, T*=TFirmly+273.15；Te *=Te+273.15；FtciIt is oil-pipe external wall surface to sleeve pipe Inner wall surface radiates coefficient of efficiency；εoFor oil-pipe external wall blackness；εciFor internal surface of sleeve pipe blackness；δ is that Stefan-Boltzmann is normal Number, δ=2.189 × 10-8W/(m2·K)。
  8. 8. the computational methods of natural gas well wellbore pressure according to claim 7 and the distributed data of temperature, its feature exist In, it is described according to the associated parameter data, as initial calculation point, to calculate each wellbore section successively at natural gas well pit shaft well head The pressure value in exit and the temperature value in each wellbore section exit, in addition to：
    According to formula：
    <mrow> <mi>f</mi> <mrow> <mo>(</mo> <mi>t</mi> <mo>)</mo> </mrow> <mo>=</mo> <mn>1.1281</mn> <msqrt> <msub> <mi>t</mi> <mi>D</mi> </msub> </msqrt> <mrow> <mo>(</mo> <mn>1</mn> <mo>-</mo> <mn>0.3</mn> <msqrt> <msub> <mi>t</mi> <mi>D</mi> </msub> </msqrt> <mo>)</mo> </mrow> <mo>,</mo> <msup> <mn>10</mn> <mrow> <mo>-</mo> <mn>10</mn> </mrow> </msup> <mo>&amp;le;</mo> <msub> <mi>t</mi> <mi>D</mi> </msub> <mo>&amp;le;</mo> <mn>1.5</mn> <mo>;</mo> </mrow>
    <mrow> <mi>f</mi> <mrow> <mo>(</mo> <mi>t</mi> <mo>)</mo> </mrow> <mo>=</mo> <mrow> <mo>(</mo> <mn>0.4063</mn> <mo>+</mo> <mn>0.5</mn> <mi>ln</mi> <mi> </mi> <msub> <mi>t</mi> <mi>D</mi> </msub> <mo>)</mo> </mrow> <mrow> <mo>(</mo> <mn>1</mn> <mo>+</mo> <mfrac> <mn>0.6</mn> <msub> <mi>t</mi> <mi>D</mi> </msub> </mfrac> <mo>)</mo> </mrow> <mo>,</mo> <msub> <mi>t</mi> <mi>D</mi> </msub> <mo>&gt;</mo> <mn>1.5</mn> <mo>;</mo> </mrow>
    Determine Ramey non dimensional time function f (t).
  9. 9. the computational methods of natural gas well wellbore pressure according to claim 8 and the distributed data of temperature, its feature exist In, it is described according to the associated parameter data, as initial calculation point, to calculate each wellbore section successively at natural gas well pit shaft well head The pressure value in exit and the temperature value in each wellbore section exit, in addition to：
    According to formula：
    <mrow> <msub> <mi>U</mi> <mrow> <mi>t</mi> <mi>o</mi> </mrow> </msub> <mo>=</mo> <msup> <mrow> <mo>&amp;lsqb;</mo> <mfrac> <msub> <mi>r</mi> <mrow> <mi>t</mi> <mi>o</mi> </mrow> </msub> <mrow> <msub> <mi>r</mi> <mrow> <mi>t</mi> <mi>i</mi> </mrow> </msub> <msub> <mi>h</mi> <mi>f</mi> </msub> </mrow> </mfrac> <mo>+</mo> <mfrac> <mrow> <msub> <mi>r</mi> <mrow> <mi>t</mi> <mi>o</mi> </mrow> </msub> <mi>ln</mi> <mrow> <mo>(</mo> <mfrac> <msub> <mi>r</mi> <mrow> <mi>t</mi> <mi>o</mi> </mrow> </msub> <msub> <mi>r</mi> <mrow> <mi>t</mi> <mi>i</mi> </mrow> </msub> </mfrac> <mo>)</mo> </mrow> </mrow> <msub> <mi>K</mi> <mrow> <mi>t</mi> <mi>u</mi> <mi>b</mi> </mrow> </msub> </mfrac> <mo>+</mo> <mfrac> <msub> <mi>r</mi> <mrow> <mi>t</mi> <mi>o</mi> </mrow> </msub> <mrow> <msub> <mi>r</mi> <mrow> <mi>c</mi> <mi>i</mi> </mrow> </msub> <mrow> <mo>(</mo> <msub> <mi>h</mi> <mi>c</mi> </msub> <mo>+</mo> <msub> <mi>h</mi> <mi>r</mi> </msub> <mo>)</mo> </mrow> </mrow> </mfrac> <mo>+</mo> <mfrac> <mrow> <msub> <mi>r</mi> <mrow> <mi>t</mi> <mi>o</mi> </mrow> </msub> <mi>ln</mi> <mrow> <mo>(</mo> <mfrac> <msub> <mi>r</mi> <mrow> <mi>c</mi> <mi>o</mi> </mrow> </msub> <msub> <mi>r</mi> <mrow> <mi>c</mi> <mi>i</mi> </mrow> </msub> </mfrac> <mo>)</mo> </mrow> </mrow> <msub> <mi>K</mi> <mrow> <mi>c</mi> <mi>a</mi> <mi>s</mi> </mrow> </msub> </mfrac> <mo>+</mo> <mfrac> <mrow> <msub> <mi>r</mi> <mrow> <mi>t</mi> <mi>o</mi> </mrow> </msub> <mi>ln</mi> <mrow> <mo>(</mo> <mfrac> <msub> <mi>r</mi> <mi>h</mi> </msub> <msub> <mi>r</mi> <mrow> <mi>c</mi> <mi>o</mi> </mrow> </msub> </mfrac> <mo>)</mo> </mrow> </mrow> <msub> <mi>K</mi> <mi>e</mi> </msub> </mfrac> <mo>&amp;rsqb;</mo> </mrow> <mrow> <mo>-</mo> <mn>1</mn> </mrow> </msup> </mrow>
    Determine oil pipe to total thermal conductivity factor U on stratumto。
  10. 10. the computational methods of natural gas well wellbore pressure according to claim 9 and the distributed data of temperature, its feature exist In, it is described according to the associated parameter data, as initial calculation point, to calculate each wellbore section successively at natural gas well pit shaft well head The pressure value in exit and the temperature value in each wellbore section exit, in addition to：
    Determine the pressure difference value dP of i-th of wellbore section exit and porchi：
    dPi=Pi+1-Pi；
    Determine the gas mean flow rate of i-th of wellbore sectionWith the gas flow rate difference in i-th of wellbore section exit and porch dvi：
    <mrow> <mover> <msub> <mi>v</mi> <mi>i</mi> </msub> <mo>&amp;OverBar;</mo> </mover> <mo>=</mo> <mfrac> <mrow> <msub> <mi>v</mi> <mi>i</mi> </msub> <mo>+</mo> <msub> <mi>v</mi> <mrow> <mi>i</mi> <mo>+</mo> <mn>1</mn> </mrow> </msub> </mrow> <mn>2</mn> </mfrac> <mo>;</mo> </mrow>
    dvi=vi+1-vi；
    Wherein,
  11. 11. the computational methods of natural gas well wellbore pressure according to claim 10 and the distributed data of temperature, its feature It is, it is described according to the associated parameter data, as initial calculation point, to calculate each pit shaft successively at natural gas well pit shaft well head The section pressure value in exit and the temperature value in each wellbore section exit, in addition to：
    According to formula：
    <mrow> <msub> <mi>T</mi> <mrow> <mi>i</mi> <mo>+</mo> <mn>1</mn> </mrow> </msub> <mo>=</mo> <msub> <mi>T</mi> <mrow> <mi>e</mi> <mi>i</mi> <mo>+</mo> <mn>1</mn> </mrow> </msub> <mo>+</mo> <mfrac> <mrow> <mn>1</mn> <mo>-</mo> <msup> <mi>e</mi> <mi>N</mi> </msup> <mi>d</mi> <mi>l</mi> </mrow> <mi>N</mi> </mfrac> <mo>&amp;times;</mo> <mrow> <mo>(</mo> <mfrac> <mrow> <mo>-</mo> <mi>g</mi> <mi> </mi> <mi>sin</mi> <mi>&amp;theta;</mi> </mrow> <msub> <mi>C</mi> <mrow> <mi>p</mi> <mi>g</mi> </mrow> </msub> </mfrac> <mo>+</mo> <msub> <mi>C</mi> <mi>J</mi> </msub> <mfrac> <mrow> <msub> <mi>dP</mi> <mi>i</mi> </msub> </mrow> <mrow> <mi>d</mi> <mi>l</mi> </mrow> </mfrac> <mo>-</mo> <mfrac> <mover> <mrow> <mi>v</mi> <mi>i</mi> </mrow> <mo>&amp;OverBar;</mo> </mover> <msub> <mi>C</mi> <mrow> <mi>p</mi> <mi>g</mi> </mrow> </msub> </mfrac> <mfrac> <mrow> <msub> <mi>dv</mi> <mi>i</mi> </msub> </mrow> <mrow> <mi>d</mi> <mi>l</mi> </mrow> </mfrac> <mo>+</mo> <msub> <mi>g</mi> <mi>T</mi> </msub> <mi>sin</mi> <mi>&amp;theta;</mi> <mo>+</mo> <mfrac> <mrow> <mi>f</mi> <msup> <mover> <mrow> <mi>v</mi> <mi>i</mi> </mrow> <mo>&amp;OverBar;</mo> </mover> <mn>2</mn> </msup> </mrow> <mrow> <mn>2</mn> <msub> <mi>C</mi> <mrow> <mi>p</mi> <mi>g</mi> </mrow> </msub> <mi>D</mi> </mrow> </mfrac> <mo>)</mo> </mrow> <mo>+</mo> <msup> <mi>e</mi> <mrow> <mi>N</mi> <mi>d</mi> <mi>l</mi> </mrow> </msup> <mrow> <mo>(</mo> <msub> <mi>T</mi> <mi>i</mi> </msub> <mo>-</mo> <msub> <mi>T</mi> <mrow> <mi>e</mi> <mi>i</mi> </mrow> </msub> <mo>)</mo> </mrow> <mo>;</mo> </mrow>
    Calculate the calculating temperature value T in i-th of wellbore section exiti+1；
    Wherein, Tei+1For the formation temperature in i-th of wellbore section exit；TeiFor the formation temperature of i-th of wellbore section porch；KeFor the formation thermal conductivity of i-th of wellbore section；GgFor gas mass velocity.
  12. 12. the computational methods of natural gas well wellbore pressure according to claim 11 and the distributed data of temperature, its feature It is, it is described according to the associated parameter data, as initial calculation point, to calculate each pit shaft successively at natural gas well pit shaft well head The section pressure value in exit and the temperature value in each wellbore section exit, in addition to：
    Judge | Ti+1-Ti+1' | whether less than one first predetermined threshold value, and | Pi+1-Pi+1' | whether less than one second default threshold Value；
    If | Ti+1-Ti+1' | less than one first predetermined threshold value, and | Pi+1-Pi+1' | less than one second predetermined threshold value, determine described i-th The calculating pressure value P in individual wellbore section exiti+1With the calculating temperature value T in i-th of wellbore section exiti+1Accurately；And will Pi+1As the pressure value of i+1 wellbore section porch, by Ti+1As the temperature value of i+1 wellbore section porch, continue Calculate the calculating pressure value in i+1 wellbore section exit and calculate temperature value；
    If | Ti+1-Ti+1' | more than or equal to first predetermined threshold value, or | Pi+1-Pi+1' | more than or equal to the described second default threshold Value, then redefine Pi+1' it is equal to Pi+1, and Ti+1' it is equal to Ti+1, and recalculate the average pressure value of i-th of wellbore sectionWith The average temperature value of i-th of wellbore section
  13. 13. the computational methods of natural gas well wellbore pressure according to claim 12 and the distributed data of temperature, its feature It is, it is determined that the calculating pressure value P in i-th of wellbore section exiti+1With the calculating in i-th of wellbore section exit Temperature value Ti+1After accurate, methods described also includes：
    Count the material calculation and l of currently calculated each pit shaft；
    If l >=H, it is determined that the pressure value in each wellbore section exit in the natural gas well pit shaft and each wellbore section exit Temperature value is calculated and finished.
CN201510520092.0A 2015-08-21 2015-08-21 A kind of computational methods of natural gas well wellbore pressure and the distributed data of temperature Active CN105134179B (en)

Priority Applications (1)

Application Number Priority Date Filing Date Title
CN201510520092.0A CN105134179B (en) 2015-08-21 2015-08-21 A kind of computational methods of natural gas well wellbore pressure and the distributed data of temperature

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
CN201510520092.0A CN105134179B (en) 2015-08-21 2015-08-21 A kind of computational methods of natural gas well wellbore pressure and the distributed data of temperature

Publications (2)

Publication Number Publication Date
CN105134179A CN105134179A (en) 2015-12-09
CN105134179B true CN105134179B (en) 2018-02-02

Family

ID=54719716

Family Applications (1)

Application Number Title Priority Date Filing Date
CN201510520092.0A Active CN105134179B (en) 2015-08-21 2015-08-21 A kind of computational methods of natural gas well wellbore pressure and the distributed data of temperature

Country Status (1)

Country Link
CN (1) CN105134179B (en)

Families Citing this family (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN105952443A (en) * 2016-05-31 2016-09-21 中国石油天然气股份有限公司 Determination method and device for wellbore temperature distribution of flue gas flooding gas-injection well
CN106503299A (en) * 2016-09-27 2017-03-15 中国石油天然气股份有限公司 Steamed well pit shaft overall heat-transfer coefficient computational methods
CN112796704B (en) * 2019-10-28 2023-07-28 中国石油化工股份有限公司 Optimization method for oil well hot washing paraffin removal mode and parameter optimization method
CN113536212B (en) * 2020-04-15 2024-04-02 中国石油化工股份有限公司 Bottom hole pressure determining method based on gas-liquid two-phase pipe flow model
CN113969779B (en) * 2020-07-22 2023-10-27 中国石油天然气股份有限公司 Method for determining pressure distribution of gas injection well shaft
CN112763399B (en) * 2020-12-28 2021-09-21 西安特种设备检验检测院 Method for detecting flue gas corrosion risk area of low-temperature heating surface of boiler

Family Cites Families (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US8543336B2 (en) * 2008-10-22 2013-09-24 Baker Hughes Incorporated Distributed measurement of mud temperature
EP2597253B1 (en) * 2011-11-25 2015-10-07 Services Pétroliers Schlumberger Dynamic prediction of downhole temperature distributions
CN104389589B (en) * 2014-10-11 2017-02-15 中国石油天然气股份有限公司 Method and system of determining shaft temperature field distribution based on hollow-rod
CN104453861B (en) * 2014-11-11 2017-03-08 中国石油天然气股份有限公司 A kind of determination method of high-pressure gas well well bore temperature distribution and system
CN104806230B (en) * 2015-02-16 2018-01-05 中国石油天然气股份有限公司 The Wellbore Temperature Field of overcritical steam injection well and the computational methods of pressure field distribution

Also Published As

Publication number Publication date
CN105134179A (en) 2015-12-09

Similar Documents

Publication Publication Date Title
CN105134179B (en) A kind of computational methods of natural gas well wellbore pressure and the distributed data of temperature
CN104453861B (en) A kind of determination method of high-pressure gas well well bore temperature distribution and system
CN103775058B (en) A kind of determination method of wellbore heat loss
CN104806230B (en) The Wellbore Temperature Field of overcritical steam injection well and the computational methods of pressure field distribution
CN105160161B (en) Thermal parameter determines method and device in pit shaft
CN104389589B (en) Method and system of determining shaft temperature field distribution based on hollow-rod
CN104481482B (en) Horizontal well concentric double pipe gas injection Heat-Insulated Analysis method and device
CN104850681B (en) The steam of injection, the temperature of nitrogen mixture, pressure, the computational methods of mass dryness fraction
CN106770439A (en) Rock-soil layer is layered Determination of conductive coefficients method
CN104807850B (en) It is a kind of measure oil/gas well wellbore fluids, oil well pipe thermodynamic parameter experimental provision and method
CN105422084B (en) A kind of the Wellbore Temperature Field acquisition methods and device of hot water circulation heated viscosity reduction technique
CN110104368B (en) Salt cavern gas storage natural gas inventory prediction method
CN109948182A (en) A kind of calculation method for mid-deep strata geothermal well well spacing
CN105370255B (en) The determination method and device of the general gas injection electric ignition well bore temperature distribution of combustion in situ
CN104376188B (en) A kind of computational methods of geothermal well heat loss
CN102682195B (en) Semisubmersible platform transient state bored shaft temperature computation method
CN107575214A (en) The Forecasting Methodology of temperature and pressure in the pit shaft of process is adopted for noting
CN106503299A (en) Steamed well pit shaft overall heat-transfer coefficient computational methods
CN109033012B (en) Method and device for determining temperature field of hollow sucker rod hot water injection circulation shaft
Li et al. Comparison of the experimental and numerical results of coaxial-type and U-type deep-buried pipes’ heat transfer performances
CN102777159A (en) CO2(Carbon Dioxide)-injection well shaft flow state confirmation and parameter optimization method
CN105184061B (en) The method for numerical simulation of gas-producing well temperature, pressure distribution
CN105370266B (en) Combustion in situ layering electric ignition gas injection well well bore temperature distribution determines method and device
Galate et al. Downward Two-Phase Flow Effects in Heat-Loss and Pressure-Drop Modeling of Steam Injection Wells
CN105114060B (en) A kind of method and device for the well bore temperature distribution for calculating gas injection well

Legal Events

Date Code Title Description
C06 Publication
PB01 Publication
C10 Entry into substantive examination
SE01 Entry into force of request for substantive examination
GR01 Patent grant
GR01 Patent grant