CN106021958A - Method and device for determining temperatures of upper end and lower end of gas injection well packer - Google Patents
Method and device for determining temperatures of upper end and lower end of gas injection well packer Download PDFInfo
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- CN106021958A CN106021958A CN201610416823.1A CN201610416823A CN106021958A CN 106021958 A CN106021958 A CN 106021958A CN 201610416823 A CN201610416823 A CN 201610416823A CN 106021958 A CN106021958 A CN 106021958A
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- 238000000034 method Methods 0.000 title claims abstract description 103
- 238000002347 injection Methods 0.000 title claims abstract description 34
- 239000007924 injection Substances 0.000 title claims abstract description 34
- 238000009413 insulation Methods 0.000 claims abstract description 20
- 238000009826 distribution Methods 0.000 claims abstract description 19
- 230000015572 biosynthetic process Effects 0.000 claims description 16
- 238000012546 transfer Methods 0.000 claims description 16
- 239000004568 cement Substances 0.000 claims description 11
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 6
- 239000002699 waste material Substances 0.000 claims description 3
- 239000004744 fabric Substances 0.000 claims 1
- 238000011084 recovery Methods 0.000 abstract description 16
- 230000000694 effects Effects 0.000 abstract description 13
- 238000010793 Steam injection (oil industry) Methods 0.000 abstract description 10
- 239000003129 oil well Substances 0.000 abstract description 6
- 239000003921 oil Substances 0.000 description 16
- 239000000203 mixture Substances 0.000 description 5
- 238000003860 storage Methods 0.000 description 5
- 238000005516 engineering process Methods 0.000 description 3
- 238000010438 heat treatment Methods 0.000 description 3
- 230000001133 acceleration Effects 0.000 description 2
- 230000000295 complement effect Effects 0.000 description 2
- 230000005484 gravity Effects 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- 238000005457 optimization Methods 0.000 description 2
- 238000007789 sealing Methods 0.000 description 2
- 230000005514 two-phase flow Effects 0.000 description 2
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 1
- CDBYLPFSWZWCQE-UHFFFAOYSA-L Sodium Carbonate Chemical compound [Na+].[Na+].[O-]C([O-])=O CDBYLPFSWZWCQE-UHFFFAOYSA-L 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 230000000903 blocking effect Effects 0.000 description 1
- 210000004556 brain Anatomy 0.000 description 1
- 229910052799 carbon Inorganic materials 0.000 description 1
- 230000006835 compression Effects 0.000 description 1
- 238000007906 compression Methods 0.000 description 1
- 238000004590 computer program Methods 0.000 description 1
- 230000001143 conditioned effect Effects 0.000 description 1
- 238000012937 correction Methods 0.000 description 1
- 230000005611 electricity Effects 0.000 description 1
- 238000001914 filtration Methods 0.000 description 1
- 239000000295 fuel oil Substances 0.000 description 1
- 229910002804 graphite Inorganic materials 0.000 description 1
- 239000010439 graphite Substances 0.000 description 1
- 239000004615 ingredient Substances 0.000 description 1
- 238000009434 installation Methods 0.000 description 1
- 230000010354 integration Effects 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 239000007791 liquid phase Substances 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 230000003287 optical effect Effects 0.000 description 1
- 238000012856 packing Methods 0.000 description 1
- 239000012071 phase Substances 0.000 description 1
- 229950000845 politef Drugs 0.000 description 1
- 230000005855 radiation Effects 0.000 description 1
- 229920006395 saturated elastomer Polymers 0.000 description 1
- 230000011218 segmentation Effects 0.000 description 1
- 238000006467 substitution reaction Methods 0.000 description 1
- 238000003786 synthesis reaction Methods 0.000 description 1
- 230000008646 thermal stress Effects 0.000 description 1
- 230000036962 time dependent Effects 0.000 description 1
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
- E21B47/07—Temperature
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- G—PHYSICS
- G16—INFORMATION AND COMMUNICATION TECHNOLOGY [ICT] SPECIALLY ADAPTED FOR SPECIFIC APPLICATION FIELDS
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Abstract
The invention relates to the field of steam injection thermal recovery of thickened oil, in particular to a method and device for determining the temperatures of the upper end and the lower end of a gas injection well packer. The method includes the steps that the temperature field distribution of steam in a gas injection well heat insulation pipe is acquired; the temperature field distribution of the outer wall of the heat insulation pipe and the temperature field distribution of the inner wall of a casing pipe are acquired according to the temperature field distribution of the steam in the heat insulation pipe; the temperature of the lower end of the packer and the temperature of the upper end of the packer are acquired according to the temperature field distribution of the outer wall of the heat insulation pipe and the temperature field distribution of the inner wall of the casing pipe. According to the method, the temperature of the upper end of the packer and the temperature of the lower end of the packer are calculated, and therefore the position of the packer can be optimized; the method is of great guiding significance on improvement of the heat insulation effect of a gas injection well, prolonging of the thermal recovery life of an oil well and improvement of the quality of steam and the oil well thermal recovery effect.
Description
Technical field
The present invention relates to thick oil filling steam oil recovery by heating field, particularly relate to gas injection well packer upper and lower two ends temperature really
Determine method and device.
Background technology
Steam injection oil recovery by heating is based on thermodynamics and the theory of thermal conduction study and method, coagulates oil based on viscous crude and height
Object to be exploited, reduces Crude viscosity by mode of heating (injection steam), releases oil layer blocking, improves stratum filtration special
Property, thus improve the production technique of oil recovery factor.At present, the heat insulation mode of land steam thermal recovery of heavy oil field power DP technology makes mostly
By the heat insulation technique of " instlated tubular+packer ", under this technique, owing to the heat enthalpy value of steam is much larger than the air of annular space, because of
This some steam enters annular space and causes annular space temperature to raise, thus sleeve pipe can be caused fatigue damage;Packer be for
Sealing oil jacket annular space, such that it is able to avoid thermal stress to act directly on sleeve pipe, and the position of packer can direct shadow
Ring protected effect.But, current packer installation site is not fixed, but the most arbitrarily lays, thus have impact on envelope
Protected effect every device.
Summary of the invention
The embodiment of the present application provides the determination method and device of a kind of gas injection well packer upper and lower two ends temperature, to optimize
Packer location, improves well thermal recovery effect.
For reaching above-mentioned purpose, on the one hand, the embodiment of the present application provides gas injection well packer upper and lower two ends temperature really
Determining method, described method includes:
The thermo parameters method of steam in acquisition gas injection well instlated tubular;
According to the thermo parameters method of steam in described instlated tubular, obtain thermo parameters method and the internal surface of sleeve pipe of instlated tubular outer wall
Thermo parameters method;
Thermo parameters method according to described instlated tubular outer wall and the thermo parameters method of described internal surface of sleeve pipe, obtain under packer
The temperature of end and the temperature of packer upper end.
Further, the described temperature of acquisition packer lower end and the temperature of packer upper end include:
Calculate the mean heat loss of packer lower end;
Under thermo parameters method, the thermo parameters method of described internal surface of sleeve pipe and described packer according to described instlated tubular outer wall
The mean heat loss of end, calculates the temperature of packer lower end;
Calculate the mean heat loss of packer;
Temperature according to described packer lower end and the mean heat loss of described packer, calculate the temperature of packer upper end
Degree.
Further, the temperature of described packer lower end calculates according to the following equation:
TF=TE-Q1*R′/dh
Wherein,
In formula: TFTemperature for packer lower end;TEFor the temperature at instlated tubular end outlet;Q1For instlated tubular lower end
Mean heat loss;Dh is steam (vapor) outlet to the distance of packer lower end;hfFor moisture film heat transfer coefficient;rciFor internal surface of sleeve pipe radius.
Further, the temperature of described packer upper end calculates according to the following equation:
TG=TF-Q2*R″/dh
Wherein,
In formula: TGTemperature for packer upper end;TFTemperature for packer lower end;Q2Mean heat loss for instlated tubular;
Dh is steam (vapor) outlet to the distance of Thermal packer lower end;KfFor packer axial thermal conductivity coefficient;LfAxial effective for packer
Length.
Further, in described instlated tubular, the thermo parameters method of steam calculates according to the following equation:
Ts=195.94P0.225-17.8
Wherein, TsFor the temperature of steam in instlated tubular, P is the pressure of steam in instlated tubular.
Further, the thermo parameters method of described instlated tubular outer wall calculates according to the following equation:
To=Ts-(R1+R2+R3+R4)dq/dl
Wherein,
In formula: T0For instlated tubular outside wall temperature;TsFor the temperature of steam in instlated tubular;Dl is well segment length, and dq is well segment length
Heat loss on degree dl;hfFor moisture film heat transfer coefficient;rtiFor insulated tubing inner tube wall radius;KtubFor oil pipe heat conductivity;rto
For insulated tubing outer wall of inner tube radius;KinsFor heat insulation layer heat conductivity;riFor insulated tubing outer tube wall radius;roFor insulation oil
Pipe outer tube outer wall radius.
Further, the thermo parameters method of described internal surface of sleeve pipe calculates according to the following equation:
Tci=Te+(R6+R7+R8)dq/dl
Wherein,
In formula, TciFor instlated tubular outside wall temperature;TeFor formation temperature;Dl is well segment length, and dq is in well segment length dl
Heat loss;rciFor internal surface of sleeve pipe radius;rcoFor sleeve outer wall radius;rhFor cement sheath radius;KcasFor sleeve pipe heat conductivity;Kcem
For cement sheath heat conductivity;KeFor formation thermal conductivity;F (t) is Ramey time function.
On the other hand, the embodiment of the present application additionally provides the determination device of a kind of gas injection well packer upper and lower two ends temperature,
Described device includes:
First computing unit, the thermo parameters method of steam in obtaining gas injection well instlated tubular;
Second computing unit, for according to the thermo parameters method of steam in described instlated tubular, obtaining the temperature of instlated tubular outer wall
Degree field distribution and the thermo parameters method of internal surface of sleeve pipe;
3rd computing unit, for the thermo parameters method according to described instlated tubular outer wall and the temperature field of described internal surface of sleeve pipe
Distribution, obtains temperature and the temperature of packer upper end of packer lower end.
Further, described 3rd computing unit includes:
Packer lower end heat loss computation subunit, for calculating the mean heat loss of packer lower end;
Packer lower temperature computation subunit, for according to the thermo parameters method of described instlated tubular outer wall, described sleeve pipe
The thermo parameters method of inwall and the mean heat loss of described packer lower end, calculate the temperature of packer lower end;
Packer heat loss computation subunit, for calculating the mean heat loss of packer;
Packer upper end temperature computation subelement, flat for according to the temperature of described packer lower end and described packer
All heat loss, calculate the temperature of packer upper end.
Further, the temperature of described packer lower end calculates according to the following equation:
TF=TE-Q1*R′/dh
Wherein,
In formula: TFTemperature for packer lower end;TEFor the temperature at instlated tubular end outlet;Q1For instlated tubular lower end
Mean heat loss;Dh is steam (vapor) outlet to the distance of packer lower end;hfFor moisture film heat transfer coefficient;rciFor internal surface of sleeve pipe radius.
Further, the temperature of described packer upper end calculates according to the following equation:
TG=TF-Q2*R″/dh
Wherein,
In formula: TGTemperature for packer upper end;TFTemperature for packer lower end;Q2Mean heat loss for instlated tubular;
Dh is steam (vapor) outlet to the distance of Thermal packer lower end;KfFor packer axial thermal conductivity coefficient;LfAxial effective for packer
Length.
Further, in described instlated tubular, the thermo parameters method of steam calculates according to the following equation:
Ts=195.94P0.225-17.8
Wherein, TsFor the temperature of steam in instlated tubular, P is the pressure of steam in instlated tubular.
Further, the thermo parameters method of described instlated tubular outer wall calculates according to the following equation:
To=Ts-(R1+R2+R3+R4)dq/dl
Wherein,
In formula: T0For instlated tubular outside wall temperature;TsFor the temperature of steam in instlated tubular;Dl is well segment length, and dq is well segment length
Heat loss on degree dl;hfFor moisture film heat transfer coefficient;rtiFor insulated tubing inner tube wall radius;KtubFor oil pipe heat conductivity;rto
For insulated tubing outer wall of inner tube radius;KinsFor heat insulation layer heat conductivity;riFor insulated tubing outer tube wall radius;roFor insulation oil
Pipe outer tube outer wall radius.
Further, the thermo parameters method of described internal surface of sleeve pipe calculates according to the following equation:
Tci=Te+(R6+R7+R8)dq/dl
Wherein,
In formula, TciFor instlated tubular outside wall temperature;TeFor formation temperature;Dl is well segment length, and dq is in well segment length dl
Heat loss;rciFor internal surface of sleeve pipe radius;rcoFor sleeve outer wall radius;rhFor cement sheath radius;KcasFor sleeve pipe heat conductivity;Kcem
For cement sheath heat conductivity;KeFor formation thermal conductivity;F (t) is Ramey time function.
The determination method and device of a kind of gas injection well packer upper and lower two ends temperature that the embodiment of the present application provides, first obtains
Take the thermo parameters method of steam in gas injection well instlated tubular, then determine that the thermo parameters method of instlated tubular outer wall and internal surface of sleeve pipe
Thermo parameters method, calculates under packer finally according to the thermo parameters method of instlated tubular outer wall and the thermo parameters method of internal surface of sleeve pipe
The temperature of end and the temperature of packer upper end.The application calculates temperature and the temperature of packer lower end of packer upper end, from
And can according to this guide field operation, optimize packer location, thus to the effect of heat insulation of gas injection well, the thermal recovery life-span of oil well with
And the raising of quality of steam and well thermal recovery effect has important directive significance.
Accompanying drawing explanation
In order to be illustrated more clearly that the embodiment of the present application or technical scheme of the prior art, below will be to embodiment or existing
In having technology to describe, the required accompanying drawing used is briefly described, it should be apparent that, the accompanying drawing in describing below is only this
Some embodiments described in application, for those of ordinary skill in the art, in the premise not paying creative work
Under, it is also possible to other accompanying drawing is obtained according to these accompanying drawings.
Fig. 1 is the structural representation of the gas injection well pit shaft of the embodiment of the present application;
Fig. 2 is the flow chart of the determination method of the gas injection well packer upper and lower two ends temperature of the embodiment of the present application;
Fig. 3 is the structure chart of the determination device of the gas injection well packer upper and lower two ends temperature of the embodiment of the present application.
Detailed description of the invention
For the technical scheme making those skilled in the art be more fully understood that in the application, real below in conjunction with the application
Execute the accompanying drawing in example, the technical scheme in the embodiment of the present application is clearly and completely described, it is clear that described enforcement
Example is only some embodiments of the present application rather than whole embodiments.Based on the embodiment in the application, this area is common
The every other embodiment that technical staff is obtained under not making creative work premise, all should belong to the application protection
Scope.
Below in conjunction with the accompanying drawings, the detailed description of the invention of the embodiment of the present application is described in further detail.
With reference to Fig. 2, the embodiment of the present application provides the determination method of a kind of gas injection well packer upper and lower two ends temperature, the party
Method includes that steps S1 is to step S3.
The thermo parameters method of steam in S1, acquisition gas injection well instlated tubular.
S2, according to the thermo parameters method of steam in described instlated tubular, obtain thermo parameters method and the sleeve pipe of instlated tubular outer wall
The thermo parameters method of inwall.
S3, according to the thermo parameters method of described instlated tubular outer wall and the thermo parameters method of described internal surface of sleeve pipe, obtain packing
The temperature of device lower end and the temperature of packer upper end.
By said method, the temperature of steam, the temperature of instlated tubular outer wall and the temperature of internal surface of sleeve pipe are considered
Etc. factor along the change of well depth, such that it is able to calculate the temperature at the upper and lower two ends of packer accurately, and then packer can be passed through
The up and down temperature optimization packer location at two ends, to the effect of heat insulation of steam injection well, the thermal recovery life-span of oil well and quality of steam and
The raising of well thermal recovery effect has important directive significance.
Main assumption condition in the embodiment of the present invention is:
(1) flowing for one-dimensional stable and heat transfer in insulated tubing, flow velocity, pressure, temperature are the most axially varying, diametrically
Identical;
(2) stratum axial symmetry distribution centered by pit shaft axis, the heat transfer of cement sheath outer rim to stratum is one-dimensional and unsteady state
Heat transfer, obeys the non dimensional time function of Ramey, and does not consider the heat transfer along well depth direction;
(3) oil jacket annular space is full of air and part water (will be partially converted into water vapour during steam injection);
(4) ignore the change along well depth direction of formation thermal conductivity and geothermal gradient, and be considered a constant;
(5) packer sealing condition is good, No leakage phenomenon;
(6) packer is compression, main heat-barrier material be politef and graphite meet material, effective length is big
It is about 150~200mm.
It is gas injection well structural representation as described in Figure 1, in one embodiment, before step S1, also includes:
Obtain the associated parameter data of gas injection well pit shaft.
Concrete, described associated parameter data, including:
Casing programme and relevant thermophysical property: cement heat conductivity Kcem;Well radius rh;Instlated tubular degree of depth h;Heat insulation
Pipe heat conductivity Kins;Instlated tubular inner tube diameter rti;Instlated tubular inner tube external diameter rto;Instlated tubular outer tube external diameter ro;In instlated tubular outer tube
Footpath ri;Casing inner diameter rci;Sleeve outer rco;Packer axial thermal conductivity COEFFICIENT Kf;Axial effective length L of packerf;Steam
Vapor outlet is to distance dh of packer lower end;Steam injection pressure;Steam injection mass dryness fraction;Steam injection speed;The steam injection time;Geothermal gradient;Earth's surface
Temperature;Formation thermal conductivity.
In one embodiment, the thermo parameters method of steam in described acquisition gas injection well instlated tubular, including:
The pressure field distribution of steam in calculating instlated tubular;
According to the pressure field distribution of steam in described instlated tubular, calculate the thermo parameters method of steam in described instlated tubular.
Concrete, the embodiment of the present application, when calculating the field distribution of steam in instlated tubular, can use the side that segmentation calculates
Formula, will be divided into the infinitesimal section of several a length of dl by gas injection well pit shaft, may then pass through the side of integration from well head to shaft bottom
Method tries to achieve the field distribution of steam in instlated tubular.
Steam in instlated tubular can be considered as steam water two phase flow, and in instlated tubular, the pressure drop of steam water two phase flow is that friction is damaged
Mistake, potential variation and the synthesis result of kinetic energy change.The embodiment of the present application can obtain following formula according to momentum balance principle:
Dp=ρmgdl+ρmvmdl-τf
Wherein, p is the pressure of steam, τ in described instlated tubularfFor friction loss gradient, ρmFor the density of multiphase mixture, g
For acceleration of gravity, vmFor the flow velocity of multiphase mixture, dl is the infinitesimal section of described instlated tubular.
Three pressure drops of attaching most importance to respectively on the right of equal sign in above formula, accelerate pressure drop and friction pressure drop, permissible when calculating
It is positive direction in orientation, may thereby determine that the symbol before described three.
Further, the embodiment of the present application can use Beggs-Brill method, derives soda pop two on the basis of above formula
The pressure drop computing formula flowed mutually:
Wherein, fmCoefficient of frictional resistance when flowing for multiphase mixture, d is the caliber of described instlated tubular, and θ is hole angle
Complementary angle.Further, above formula refinement can be arranged and obtain calculating the pressure of steam in described instlated tubular by the embodiment of the present application
The formula of field distribution:
Wherein, p is the pressure of steam in described instlated tubular, and dl is the infinitesimal section of described instlated tubular, ρlFor density of liquid phase, ρg
For density of gas phase, HlFor liquid holdup, A is the sectional area of described instlated tubular, and g is acceleration of gravity, vmStream for multiphase mixture
Speed, fmCoefficient of frictional resistance when flowing for multiphase mixture, d is the caliber of described instlated tubular, and θ is the complementary angle of hole angle, and G is
Inject the mass flow of steam, vsgFor gas superficial flow velocity.
Calculate in described instlated tubular after the pressure field distribution of steam, can calculate according to saturated vapor temperature and pressure computing formula
Go out the thermo parameters method of steam in instlated tubular.Specifically, in described instlated tubular, the thermo parameters method of steam can be according to following public affairs
Formula calculates:
TS=195.94P0.225-17.8 (3)
Wherein, TsFor the temperature of steam in instlated tubular, p is the pressure of steam in described instlated tubular.
In one embodiment, the thermo parameters method of described instlated tubular outer wall calculates according to the following equation:
To=Ts-(R1+R2+R3+R4)dq/dl (4)
Wherein,
In formula: T0For instlated tubular outside wall temperature;TsFor the temperature of steam in instlated tubular;Dl is well segment length, and dq is well segment length
Heat loss on degree dl;hfFor moisture film heat transfer coefficient;rtiFor insulated tubing inner tube wall radius;KtubFor oil pipe heat conductivity;rto
For insulated tubing outer wall of inner tube radius;KinsFor heat insulation layer heat conductivity;riFor insulated tubing outer tube wall radius;roFor insulation oil
Pipe outer tube outer wall radius.
In one embodiment, the thermo parameters method of described internal surface of sleeve pipe calculates according to the following equation:
Tci=Te+(R6+R7+R8)dq/dl (9)
Wherein,
In formula, TciFor instlated tubular outside wall temperature;TeFor formation temperature;Dl is well segment length, and dq is in well segment length dl
Heat loss;rciFor internal surface of sleeve pipe radius;rcoFor sleeve outer wall radius;rhFor cement sheath radius;KcasFor sleeve pipe heat conductivity;Kcem
For cement sheath heat conductivity;KeFor formation thermal conductivity;F (t) is Ramey time function.At present, time dependent heat conduction passes
Heat content f (t) formula has a lot, the most frequently used WHAP model having Ramey model and K.Chiu et al..T worked as by Ramey model >
During 11d very accurately, also can use during steam injection only 1d, error only 11%.WHAP model can be used for any steam injection time, but calculates error
Up to 15%.Use Ramey model herein.
Concrete, heat loss dq in well segment length dl can be by calculating according to the following equation:
In formula, UtoFor total heat conductivity;KeFor formation thermal conductivity;rtoFor insulated tubing outer wall of inner tube radius;TsFor every
Vapor (steam) temperature in heat pipe;TeFor formation temperature;F (t) is Ramey time function.
Total heat conductivity:
Wherein entire thermal resistance:
R=R1+R2+R3+R4+R5+R6+R7+R8 (15)
In formula: R is entire thermal resistance, roFor insulated tubing outer tube outer wall radius;rciFor internal surface of sleeve pipe radius;rcoFor sleeve outer wall
Radius;rhFor cement sheath radius;hrFor oil jacket annular space radiation heat transfer coefficient;hcFor oil jacket annular space free convection heat transfer coefficient.
In one embodiment, the described thermo parameters method according to described instlated tubular outer wall and the temperature of described internal surface of sleeve pipe
Field distribution, obtains temperature and the temperature of packer upper end of packer lower end, including:
Calculate the mean heat loss of packer lower end;
Under thermo parameters method, the thermo parameters method of described internal surface of sleeve pipe and described packer according to described instlated tubular outer wall
The mean heat loss of end, calculates the temperature of packer lower end;
Calculate the mean heat loss of packer;
Temperature according to described packer lower end and the mean heat loss of described packer, calculate the temperature of packer upper end
Degree.
Concrete, can be according to below equation calculating pit shaft radially heat loss:
In formula, Q is pit shaft radially heat loss;TsFor vapor (steam) temperature in instlated tubular;TsFor formation temperature;R is entire thermal resistance.
As it is shown in figure 1, calculate radial direction heat loss Q at interface A C by formula (17)ACWith the radial direction heat waste at the BD of interface
QBD, then the mean heat loss Q of packer lower end1Can calculate according to below equation:
In one embodiment, as it is shown in figure 1, A point internal surface of sleeve pipe temperature can be calculated by formula (4), (9)
TA, B point internal surface of sleeve pipe temperature TB, M point internal surface of sleeve pipe temperature TM, C point instlated tubular outside wall temperature TC, D point instlated tubular outside wall temperature TD,
N point instlated tubular outside wall temperature TN。
In one embodiment, the temperature of described packer lower end can calculate according to the following equation:
TF=TE-Q1*R′/dh (19)
Wherein,
In formula: TFTemperature for packer lower end;TEFor the temperature at instlated tubular end outlet;Q1For instlated tubular lower end
Mean heat loss;Dh is steam (vapor) outlet to the distance of packer lower end;hfFor moisture film heat transfer coefficient;rciFor internal surface of sleeve pipe radius.
In one embodiment, radial direction heat loss Q at the MN of interface can be calculated by formula (17)MNAt the BD of interface
Radially heat loss QBD, then the mean heat loss Q of packer2Can calculate according to below equation:
The temperature of described packer upper end calculates according to the following equation:
TG=TF-Q2*R″/dh (23)
Wherein,
In formula: TGTemperature for packer upper end;TFTemperature for packer lower end;Q2Mean heat loss for instlated tubular;
Dh is steam (vapor) outlet to the distance of packer lower end, i.e. dh=AB=CD=EF;KfFor packer axial thermal conductivity coefficient;LfFor envelope
Axial effective length every device.
In one embodiment, after step s 3, also include:
The temperature of described packer lower end and the temperature of packer upper end are modified, it is thus achieved that packer lower end after correction
Temperature and the temperature of packer upper end.
Concrete, according to below equation, the temperature of described packer lower end can be modified:
In formula, TF' be revise after the temperature of packer lower end.
Specifically, according to below equation, the temperature of described packer upper end can be modified:
The embodiment of the present application is by calculating temperature and the temperature of packer lower end of packer upper end, when temperature does not meets pre-
If during condition, packer location can be adjusted, calculate the temperature of packer upper and lower side the most again, through meet pre-conditioned be
Only, such that it is able to guide field operation according to this, it is to avoid seal because of too high and sleeve pipe is caused damage every device upper and lower side temperature;Lead to simultaneously
Cross packer upper and lower side temperature optimization packer location, to the effect of heat insulation of gas injection well, the thermal recovery life-span of oil well and steam matter
The raising of amount and well thermal recovery effect has important directive significance.
As it is shown on figure 3, the embodiment of the present application additionally provides the determination device of a kind of gas injection well packer upper and lower two ends temperature,
Described device includes:
First computing unit 21, the thermo parameters method of steam in obtaining gas injection well instlated tubular;
Second computing unit 22, for according to the thermo parameters method of steam in described instlated tubular, obtaining instlated tubular outer wall
Thermo parameters method and the thermo parameters method of internal surface of sleeve pipe;
3rd computing unit 23, for the thermo parameters method according to described instlated tubular outer wall and the temperature of described internal surface of sleeve pipe
Field distribution, obtains temperature and the temperature of packer upper end of packer lower end.
In one embodiment, described 3rd computing unit includes:
Packer lower end heat loss computation subunit, for calculating the mean heat loss of packer lower end;
Packer lower temperature computation subunit, for according to the thermo parameters method of described instlated tubular outer wall, described sleeve pipe
The thermo parameters method of inwall and the mean heat loss of described packer lower end, calculate the temperature of packer lower end;
Packer heat loss computation subunit, for calculating the mean heat loss of packer;
Packer upper end temperature computation subelement, flat for according to the temperature of described packer lower end and described packer
All heat loss, calculate the temperature of packer upper end.
Each ingredient of the device of the present embodiment is respectively used to realize each step of the method for previous embodiment, due to
In embodiment of the method, each step is described in detail, has not repeated them here.
The determination method and device of a kind of gas injection well packer upper and lower two ends temperature that the embodiment of the present application provides, first counts
Calculate the thermo parameters method of steam in gas injection well instlated tubular, then determine that the thermo parameters method of instlated tubular outer wall and internal surface of sleeve pipe
Thermo parameters method, calculates under packer finally according to the thermo parameters method of instlated tubular outer wall and the thermo parameters method of internal surface of sleeve pipe
The temperature of end and the temperature of packer upper end.The application calculates temperature and the temperature of packer lower end of packer upper end, from
And can according to this guide field operation, optimize packer location, thus to the effect of heat insulation of gas injection well, the thermal recovery life-span of oil well with
And the raising of quality of steam and well thermal recovery effect has important directive significance.
In one or more exemplary designs, the above-mentioned functions described by the embodiment of the present application can be at hardware, soft
The combination in any of part, firmware or this three realizes.If realized in software, these functions can store and computer-readable
On medium, or it is transmitted on the medium of computer-readable with one or more instructions or code form.Computer readable medium includes electricity
Brain stores medium and is easy to so that allowing computer program transfer to the telecommunication media in other place from a place.Storage medium is permissible
It is that any general or special computer can be with the useable medium of access.Such as, such computer readable media can include but
It is not limited to RAM, ROM, EEPROM, CD-ROM or other optical disc storage, disk storage or other magnetic storage device, or other
What may be used for carrying or storage can be by general or special computer or general or special handling with other with instruction or data structure
Device reads the medium of the program code of form.
Particular embodiments described above, has been carried out the most in detail purpose, technical scheme and the beneficial effect of the application
Describe in detail bright, be it should be understood that the specific embodiment that the foregoing is only the embodiment of the present application, be not used to limit this Shen
Protection domain please, all within spirit herein and principle, any modification, equivalent substitution and improvement etc. done, all should wrap
Within being contained in the protection domain of the application.
Claims (14)
1. the determination method of a gas injection well packer upper and lower two ends temperature, it is characterised in that described method includes:
The thermo parameters method of steam in acquisition gas injection well instlated tubular;
According to the thermo parameters method of steam in described instlated tubular, obtain thermo parameters method and the temperature of internal surface of sleeve pipe of instlated tubular outer wall
Degree field distribution;
Thermo parameters method according to described instlated tubular outer wall and the thermo parameters method of described internal surface of sleeve pipe, obtain packer lower end
Temperature and the temperature of packer upper end.
2. the method for claim 1, it is characterised in that the temperature of described acquisition packer lower end and packer upper end
Temperature includes:
Calculate the mean heat loss of packer lower end;
Thermo parameters method, the thermo parameters method of described internal surface of sleeve pipe and described packer lower end according to described instlated tubular outer wall
Mean heat loss, calculates the temperature of packer lower end;
Calculate the mean heat loss of packer;
Temperature according to described packer lower end and the mean heat loss of described packer, calculate the temperature of packer upper end.
3. method as claimed in claim 2, it is characterised in that the temperature of described packer lower end calculates according to the following equation:
TF=TE-Q1*R′/dh
Wherein,
In formula: TFTemperature for packer lower end;TEFor the temperature at instlated tubular end outlet;Q1Average for instlated tubular lower end
Heat loss;Dh is steam (vapor) outlet to the distance of packer lower end;hfFor moisture film heat transfer coefficient;rciFor internal surface of sleeve pipe radius.
4. method as claimed in claim 3, it is characterised in that the temperature of described packer upper end calculates according to the following equation:
TG=TF-Q2*R″/dh
Wherein,
In formula: TGTemperature for packer upper end;TFTemperature for packer lower end;Q2Mean heat loss for instlated tubular;Dh is
Steam (vapor) outlet is to the distance of Thermal packer lower end;KfFor packer axial thermal conductivity coefficient;LfAxial effective for packer is long
Degree.
5. the method for claim 1, it is characterised in that in described instlated tubular, the thermo parameters method of steam is according to following public affairs
Formula calculates:
Ts=195.94P0.225-17.8
Wherein, TsFor the temperature of steam in instlated tubular, P is the pressure of steam in instlated tubular.
6. the method for claim 1, it is characterised in that the thermo parameters method of described instlated tubular outer wall is according to the following equation
Calculate:
To=Ts-(R1+R2+R3+R4)dq/dl
Wherein,
In formula: T0For instlated tubular outside wall temperature;TsFor the temperature of steam in instlated tubular;Dl is well segment length, and dq is well segment length dl
On heat loss;hfFor moisture film heat transfer coefficient;rtiFor insulated tubing inner tube wall radius;KtubFor oil pipe heat conductivity;rtoFor every
Deep fat pipe outer wall of inner tube radius;KinsFor heat insulation layer heat conductivity;riFor insulated tubing outer tube wall radius;roOutside for insulated tubing
Pipe exterior radius.
7. the method for claim 1, it is characterised in that the thermo parameters method of described internal surface of sleeve pipe is counted according to the following equation
Calculate:
Tci=Te+(R6+R7+R8)dq/dl
Wherein,
In formula, TciFor instlated tubular outside wall temperature;TeFor formation temperature;Dl is well segment length, and dq is the heat waste in well segment length dl
Lose;rciFor internal surface of sleeve pipe radius;rcoFor sleeve outer wall radius;rhFor cement sheath radius;KcasFor sleeve pipe heat conductivity;KcemFor water
Mud ring heat conductivity;KeFor formation thermal conductivity;F (t) is Ramey time function.
8. the determination device of a gas injection well packer upper and lower two ends temperature, it is characterised in that described device includes:
First computing unit, the thermo parameters method of steam in obtaining gas injection well instlated tubular;
Second computing unit, for according to the thermo parameters method of steam in described instlated tubular, obtaining the temperature field of instlated tubular outer wall
Distribution and the thermo parameters method of internal surface of sleeve pipe;
3rd computing unit, for dividing according to the thermo parameters method of described instlated tubular outer wall and the temperature field of described internal surface of sleeve pipe
Cloth, obtains temperature and the temperature of packer upper end of packer lower end.
9. device as claimed in claim 8, it is characterised in that described 3rd computing unit includes:
Packer lower end heat loss computation subunit, for calculating the mean heat loss of packer lower end;
Packer lower temperature computation subunit, for according to the thermo parameters method of described instlated tubular outer wall, described internal surface of sleeve pipe
Thermo parameters method and the mean heat loss of described packer lower end, calculate packer lower end temperature;
Packer heat loss computation subunit, for calculating the mean heat loss of packer;
Packer upper end temperature computation subelement, for the temperature according to described packer lower end and the evenly heat of described packer
Loss, calculates the temperature of packer upper end.
10. device as claimed in claim 9, it is characterised in that the temperature of described packer lower end calculates according to the following equation:
TF=TE-Q1*R′/dh
Wherein,
In formula: TFTemperature for packer lower end;TEFor the temperature at instlated tubular end outlet;Q1Average for instlated tubular lower end
Heat loss;Dh is steam (vapor) outlet to the distance of packer lower end;hfFor moisture film heat transfer coefficient;rciFor internal surface of sleeve pipe radius.
11. devices as claimed in claim 10, it is characterised in that the temperature of described packer upper end is counted according to the following equation
Calculate:
TG=TF-Q2*R″/dh
Wherein,
In formula: TGTemperature for packer upper end;TFTemperature for packer lower end;Q2Mean heat loss for instlated tubular;Dh is
Steam (vapor) outlet is to the distance of Thermal packer lower end;KfFor packer axial thermal conductivity coefficient;LfAxial effective for packer is long
Degree.
12. devices as claimed in claim 8, it is characterised in that in described instlated tubular, the thermo parameters method of steam is according to following
Formula calculates:
Ts=195.94P0.225-17.8
Wherein, TsFor the temperature of steam in instlated tubular, P is the pressure of steam in instlated tubular.
13. devices as claimed in claim 8, it is characterised in that the thermo parameters method of described instlated tubular outer wall is according to following public affairs
Formula calculates:
To=Ts-(R1+R2+R3+R4)dq/dl
Wherein,
In formula: T0For instlated tubular outside wall temperature;TsFor the temperature of steam in instlated tubular;Dl is well segment length, and dq is well segment length dl
On heat loss;hfFor moisture film heat transfer coefficient;rtiFor insulated tubing inner tube wall radius;KtubFor oil pipe heat conductivity;rtoFor every
Deep fat pipe outer wall of inner tube radius;KinsFor heat insulation layer heat conductivity;riFor insulated tubing outer tube wall radius;roOutside for insulated tubing
Pipe exterior radius.
14. devices as claimed in claim 8, it is characterised in that the thermo parameters method of described internal surface of sleeve pipe is according to the following equation
Calculate:
Tci=Te+(R6+R7+R8)dq/dl
Wherein,
In formula, TciFor instlated tubular outside wall temperature;TeFor formation temperature;Dl is well segment length, and dq is the heat waste in well segment length dl
Lose;rciFor internal surface of sleeve pipe radius;rcoFor sleeve outer wall radius;rhFor cement sheath radius;KcasFor sleeve pipe heat conductivity;KcemFor water
Mud ring heat conductivity;KeFor formation thermal conductivity;F (t) is Ramey time function.
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