CN106021659A - Method for determining corrosion rate of natural gas injection and production well pipe column under erosion-carbon dioxide corrosion coupling effect - Google Patents
Method for determining corrosion rate of natural gas injection and production well pipe column under erosion-carbon dioxide corrosion coupling effect Download PDFInfo
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- 238000005260 corrosion Methods 0.000 title claims abstract description 181
- 230000007797 corrosion Effects 0.000 title claims abstract description 181
- 229910002092 carbon dioxide Inorganic materials 0.000 title claims abstract description 64
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 title claims abstract description 60
- 239000001569 carbon dioxide Substances 0.000 title claims abstract description 58
- 238000000034 method Methods 0.000 title claims abstract description 37
- 239000003345 natural gas Substances 0.000 title claims abstract description 30
- 238000004519 manufacturing process Methods 0.000 title claims abstract description 23
- 238000002347 injection Methods 0.000 title abstract 6
- 239000007924 injection Substances 0.000 title abstract 6
- 230000001808 coupling effect Effects 0.000 title abstract 2
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 claims abstract description 86
- 230000008878 coupling Effects 0.000 claims abstract description 33
- 238000010168 coupling process Methods 0.000 claims abstract description 33
- 238000005859 coupling reaction Methods 0.000 claims abstract description 33
- 239000007789 gas Substances 0.000 claims abstract description 27
- 238000012546 transfer Methods 0.000 claims abstract description 22
- 238000009792 diffusion process Methods 0.000 claims abstract description 18
- 230000008569 process Effects 0.000 claims abstract description 13
- 239000000463 material Substances 0.000 claims abstract description 11
- 238000006056 electrooxidation reaction Methods 0.000 claims abstract description 10
- 230000007246 mechanism Effects 0.000 claims abstract description 6
- 230000003628 erosive effect Effects 0.000 claims description 52
- 239000002343 natural gas well Substances 0.000 claims description 22
- 238000004364 calculation method Methods 0.000 claims description 20
- 239000012530 fluid Substances 0.000 claims description 16
- 238000010008 shearing Methods 0.000 claims description 14
- 238000012937 correction Methods 0.000 claims description 11
- 238000013178 mathematical model Methods 0.000 claims description 11
- 238000009826 distribution Methods 0.000 claims description 9
- 230000008859 change Effects 0.000 claims description 5
- 239000011159 matrix material Substances 0.000 claims description 3
- 238000005299 abrasion Methods 0.000 claims description 2
- 230000000694 effects Effects 0.000 claims description 2
- 230000008676 import Effects 0.000 claims description 2
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 claims 2
- GWEVSGVZZGPLCZ-UHFFFAOYSA-N Titan oxide Chemical compound O=[Ti]=O GWEVSGVZZGPLCZ-UHFFFAOYSA-N 0.000 claims 2
- 229910052799 carbon Inorganic materials 0.000 claims 2
- 241000790917 Dioxys <bee> Species 0.000 claims 1
- 150000004767 nitrides Chemical class 0.000 claims 1
- 238000004080 punching Methods 0.000 claims 1
- 239000004408 titanium dioxide Substances 0.000 claims 1
- 239000007788 liquid Substances 0.000 abstract description 6
- 230000009471 action Effects 0.000 abstract description 3
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 abstract description 3
- 238000009991 scouring Methods 0.000 abstract 1
- 239000012071 phase Substances 0.000 description 11
- 238000004088 simulation Methods 0.000 description 10
- 238000004458 analytical method Methods 0.000 description 3
- 239000007791 liquid phase Substances 0.000 description 3
- 230000005540 biological transmission Effects 0.000 description 2
- 230000015572 biosynthetic process Effects 0.000 description 2
- 238000001514 detection method Methods 0.000 description 2
- 238000002474 experimental method Methods 0.000 description 2
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- 239000008187 granular material Substances 0.000 description 2
- 238000011160 research Methods 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
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- 230000007613 environmental effect Effects 0.000 description 1
- 238000005530 etching Methods 0.000 description 1
- FKLFBQCQQYDUAM-UHFFFAOYSA-N fenpiclonil Chemical compound ClC1=CC=CC(C=2C(=CNC=2)C#N)=C1Cl FKLFBQCQQYDUAM-UHFFFAOYSA-N 0.000 description 1
- 230000004907 flux Effects 0.000 description 1
- 230000003993 interaction Effects 0.000 description 1
- 238000012423 maintenance Methods 0.000 description 1
- 239000007769 metal material Substances 0.000 description 1
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- 239000004576 sand Substances 0.000 description 1
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Abstract
The invention belongs to the technical field of oilfield equipment, and particularly provides a method for determining the corrosion rate of a natural gas injection and production well pipe column under the action of erosion-carbon dioxide corrosion coupling, which comprises the following steps: 1) establishing a heat transfer, flow and diffusion model of components in the pipe column; 2) establishing a carbon dioxide corrosion model of the wall surface of the pipe column, and determining the influence of a product layer on the corrosion rate in the carbon dioxide corrosion process; 3) and establishing a wear model of the medium scouring on the pipe wall base material and the corrosion layer. 4) And coupling the three models to determine the corrosion rate of the natural gas injection and production well pipe column. According to the method, a gas well pipe column corrosion rate prediction model is established through an erosion-electrochemical corrosion coupling action mechanism in the natural gas injection and production well pipe column, so that the corrosion rate of the natural gas injection and production well pipe column can be effectively predicted, and technical reference is provided for the safety of the natural gas injection and production well pipe column carrying carbon dioxide and liquid water.
Description
Technical field
The invention belongs to technical field of oil field equipment, relate to a kind of natural gas well vertical tubing string safety clothes labour appraisal procedure, the natural gas filling under a kind of erosion-carbon dioxide corrosion coupling adopts the determination method of well casing post corrosion rate.
Background technology
Along with China's growth to clean energy resource demand, gas extraction amount constantly increases.But during gas extraction, overwhelming majority block contains CO2、H2The corrosive mediums such as O, and it is defeated with in stocking system to enter collection, this not only affects Gas Exploitation collector and delivery pipe material and the service life of processing equipment, oil and gas industry causes bigger economic loss, and environment also causes the biggest pollution.Along with the exploitation year by year of natural gas, depth of reservoirs is the most constantly deepened, the CO carried2、H2The corrosive medium content such as O change the most therewith, and the interaction of high temperature, high pressure, flow velocity and change of flow state during collecting defeated in addition and storing, tubing etching problem under flow field acts on is the most prominent.Therefore, the tube inner corrosion forecasting problem under the effect of research flow field, natural gas filling in-service for experiment instruction is adopted the detection workload of well casing column system, is ensured the safe operation of pipe tubing string system, be of great immediate significance.
Natural gas filling adopt the inner wall corrosion of well casing post not only predict, detection difficult, and transfer efficiency, equipment safety and the reliability of tubing string can be had a strong impact on.The internal corrosion of tubing string not only results in the maintenance of tubing string and shortens with the replacement cycle, and corrosion scales can affect tubing string heat transfer efficiency reduce pumped (conveying) medium flow velocity, make the conveying power source consumption of tubing string medium increase.The Complex Flows of multiphase flow understands cracking and the fracture failure phenomenon that accelerated material occurs under stress and corrosive environment synergism.Natural gas filling adopt the multiphase flow transportation characteristics in well casing post be gas phase be continuous phase, liquid phase is discontinuous phase, has the feature of erosion corrosion and carbon dioxide corrosion concurrently.The present invention is erosion corrosion and the carbon dioxide corrosion of natural gas to be combined first, in conjunction with the flow field data in natural gas course of conveying, sets up the corrosion rate forecast model of injection-production well tubing string.
In view of with physical simulation experiment, it is difficult to complex flowfield and the corrosion process of High Temperature High Pressure in the vertical tubing string of the natural gas well under simulation deeper formation, therefore, with computer numerical simulation be Main Means be the natural gas well vertical tubing string corrosion mechanism and corrosion rate predictive study developing direction from now on.
Existing erosion model have focused largely in gas-solid/liquid fixed double phase flow erosion research, the erosion rate of metal material is described in the way of mathematics with target attribute, particle habit, the Changing Pattern of environmental factors, start with from the collision process of granule impact target, by solving the energy equation of the granule equation of motion and collision, establish plastic material erosion model based on micro-cutting and formation abrasion, discussion for electrochemical corrosion course is little, is not suitable for taking liquid sour natural gas well casing band of column border without sand.
Summary of the invention
It is an object of the invention to provide the natural gas filling under a kind of erosion-electrochemical corrosion coupling and adopt the determination method of well casing post corrosion rate, the erosion in well casing post-electrochemical corrosion coupling mechanism is adopted by natural gas filling, set up gas well tube corrosion rate prediction model, it is possible to the effectively corrosion rate of Natural Gas Prediction injection-production well tubing string.
The technical scheme is that the natural gas filling under a kind of erosion-carbon dioxide corrosion coupling adopts the determination method of well casing post corrosion rate, comprise the steps:
Step one: adopt the kinestate related to according to Hydrodynamics Theory and natural gas filling, sets up the heat transfer of each component, flows and diffusion mathematical model, calculate pressure at tube wall, temperature, velocity gradient, the distribution of each concentration of component and shearing force；
Step 2: theoretical according to carbon dioxide corrosion, on the basis of the labor to gas well tube corrosion data, set up carbon dioxide corrosion model, during determining carbon dioxide corrosion, corrosion scales is for the impact of Electrochemical corrosion rate under this environment, introduces the corrosion layer thickness factor of influence to corrosion rate；
Step 3: theoretical according to erosive wear, on the basis of natural gas well note is adopted the labor of data, set up note and adopt the erosion model of process, based on fluid energy losses data, use energy theory of wear to set up erosion model, and determine that scour process is to corrosion scales and tube wall matrix erosive wear velocity coefficient；
Step 4: each model described in above step one to step 3 is carried out coupling and calculates, calculate the temperature in pipe, pressure, the inlet flow rate impact on corrosion rate, determine the safety military service parameter of natural gas well tubing string.
Flow described in above-mentioned steps one, heat transfer model uses hydrodynamics N-S Equation for Calculating；Drop motion in the gas flow introduces Wu drag force formula and Newton's second law calculates；Material diffusion in the gas flow uses Convection-Diffusion Model to calculate；By the common calculating of above-mentioned model, pressure at tube wall, temperature, velocity gradient, the distribution of each concentration of component and shearing force can be obtained.
Carbon dioxide corrosion model described in above-mentioned steps two is as follows:
In formula: the corrected parameter of a, b, d corrosion rate, T is temperature,It is CO2Dividing potential drop, pH is dielectric value, CcofIt it is corrosion rate correction factor；VcIt is carbon dioxide corrosion speed；Then introduce corrosion scales corrosion rate is modified by the factor of influence of corrosion rate: Vc'=[βhd(1+c)+α]Vc, in formula: α, β are the product layer modifying factors to corrosion rate, hd is corrosion product layer thickness, and c is corrosion rate correction factor, Vc' it is revised corrosion rate.
Above-mentioned carbon dioxide corrosion model a therein, b, d are to substitute into, according to actual corrosion rate, the parameter that model determines；α, β are to be obtained by the actual corrosion rate of foundation and corrosion scales thickness relationship.
As follows according to the erosive wear erosion model set up of theory described in above-mentioned steps three:
Wherein HfIt it is rate of depreciation；α is rate of depreciation coefficient；FwBeing shearing force, μ is medium fluid dynamic viscosity.
Above-mentioned erosion model α therein is to substitute into, according to actual erosion rate, the parameter that model determines.
Described in above-mentioned steps four, coupling calculation is: calculate pressure at tube wall, temperature, the distribution of velocity gradient each concentration of component and shearing force by flowing, heat transfer and Mass Transfer Model；By above-mentioned parameter introducing carbon dioxide erosion model, calculate the generating rate of corrosion rate and corrosion product；Corrosion product and the erosion rate of tube wall under action of a fluid is calculated by erosion model；By the corrosion scales correction term of erosion model result of calculation the most again introducing carbon dioxide erosion model, the corrosion rate calculating finally.
By importing different ambient parameters, the tube corrosion speed calculating corresponding, select the corrosion rate of safety, determine the safety military service parameter of natural gas well tubing string described in step 4.
Heat transfer described in above-mentioned steps one, flow with diffusion mathematical model solve employing fluent computed in software；And carbon dioxide corrosion, erosive wear model use the UDF User-Defined Functions of fluent software to carry out coupling calculating.
Use Fluent software, by electrochemical corrosion-erosion corrosion coupling mechanism model write UDF after natural gas well tubing string model is imported, the pressure in actual environment, concentration of component, temperature and flow parameters Input Software are carried out double precision calculating and i.e. can get result of calculation.
Beneficial effects of the present invention: the model of the present invention and method are concentrated and discussed in the vertical tubing string of natural gas injection-production well, with gas phase as continuous phase, liquid phase be discrete phase natural gas transmission during the erosion-electrochemical corrosion coupling to tube wall.In this process medium containing liquid fraction less than 1%, flow velocity is less than 25m/s.And using computer numerical simulation to calculate, result of calculation is more identical with actual Corrosion results, it is possible to provide Technical Reference for taking the natural gas well tubing string safety of carbon dioxide and aqueous water.
Hereinafter the present invention will be described in further details.
Detailed description of the invention
Embodiment 1: the natural gas filling under a kind of erosion-carbon dioxide corrosion coupling adopts the determination method of well casing post corrosion rate, is primarily based on Hydrodynamics Theory and adopts, with natural gas filling, the kinestate related to, and uses theoretical analysis method to set up mathematical model of flow field；Then theoretical according to carbon dioxide corrosion, on the basis of the labor to natural gas well corrosion data, set up carbon dioxide corrosion model；Theoretical according to carbon dioxide corrosion afterwards, on the basis of the labor to natural gas well corrosion data, set up carbon dioxide corrosion model；Finally above-mentioned model write User-Defined Functions is imported business software and carry out simulation calculation.The inventive method comprises the steps:
Step one: adopt the kinestate related to according to Hydrodynamics Theory and natural gas filling, uses theoretical analysis method to set up mathematical model of flow field, and mathematical model of flow field includes heat transfer, flowing, Mass Transfer Model.Modeling software is used to set up the tubing string model of simulated domain, node coordinate data according to each unit of Flow Field Calculation and the set corresponding relation of the block-centered grid data of Flow Field Calculation, the tubing string grid model of foundation is converted into the finite element numerical model needed for Flow Field Calculation, calculates the parameters such as pressure at tube wall, temperature, velocity gradient, the distribution of each concentration of component and shearing force.Wherein flowing, heat transfer model use hydrodynamics N-S Equation for Calculating；Drop motion in the gas flow introduces Wu drag force formula and Newton's second law calculates；Material diffusion in the gas flow uses Convection-Diffusion Model to calculate；By the common calculating of above-mentioned model, pressure at tube wall, temperature, velocity gradient, the distribution of each concentration of component and shearing force can be obtained.Heat transfer in this step, flow with diffusion mathematical model solve employing fluent computed in software；And carbon dioxide corrosion, erosive wear model use the UDF User-Defined Functions of fluent software to carry out coupling calculating.Use Fluent software, by electrochemical corrosion-erosion corrosion coupling mechanism model write UDF after natural gas well tubing string model is imported, the pressure in actual environment, concentration of component, temperature and flow parameters Input Software are carried out double precision calculating and i.e. can get result of calculation.
Step 2: theoretical according to carbon dioxide corrosion, on the basis of the labor to natural gas well tube corrosion data, set up carbon dioxide corrosion model, during determining carbon dioxide corrosion, corrosion scales is for the impact of Electrochemical corrosion rate under this environment, introduces the corrosion layer thickness factor of influence to corrosion rate.
Wherein carbon dioxide corrosion model is as follows:
In formula: the corrected parameter of a, b, d corrosion rate, T is temperature,It is CO2Dividing potential drop, pH is dielectric value, CcofIt it is corrosion rate correction factor；VcIt is carbon dioxide corrosion speed；Then introduce corrosion scales corrosion rate is modified by the factor of influence of corrosion rate: Vc'=[βhd(1+c)+α]Vc, in formula: α, β are the product layer modifying factors to corrosion rate, hd is corrosion product layer thickness, and c is corrosion rate correction factor, Vc' it is revised corrosion rate.A in carbon dioxide corrosion model, b, d are to substitute into, according to actual corrosion rate, the parameter that model determines；α, β are to be obtained by the actual corrosion rate of foundation and corrosion scales thickness relationship.
Step 3: theoretical according to erosion corrosion, on the basis of natural gas well note is adopted the labor of data, set up note and adopt the erosion model of process, based on fluid energy losses data, use energy theory of wear to set up erosion model, and determine that scour process is to corrosion scales and tube wall matrix erosive wear velocity coefficient；As follows according to the erosion model that erosive wear theory is set up:
Wherein HfIt it is rate of depreciation；α is rate of depreciation coefficient；FwBeing shearing force, μ is medium fluid dynamic viscosity.Wherein erosion model α therein is to substitute into, according to actual erosion rate, the parameter that model determines.
Step 4: each model described in above step one to step 3 is carried out coupling and calculates, calculate the temperature in pipe, pressure, the inlet flow rate impact on corrosion rate, determine the safety military service parameter of natural gas well tubing string.Particularly as follows: tubing string model step one set up imports fluent, fluent software sets border, flow field and initial condition, in fluent, select the flow field simulation calculation model of correspondence according to the flow field model in step one, boundary types and initial condition；And combining the practical situation of injection-production well, the note of input well is adopted data, is set border and the initial condition of model, the temperature in calculating simulation region, pressure, change in flow in fluent；Step 2 is coupled with erosive wear model with the carbon dioxide corrosion model in step 3, writes UDF.Flow field model in step one is imported fluent calculate, the Transient state data such as the temperature in tubing string flow field, pressure, flow velocity, carbon dioxide dividing potential drop, liquid carry over can be obtained, UDF is imported and calculates.Finally calculate the temperature in pipe, pressure, the inlet flow rate impact on corrosion rate.Coupling calculation described in this step is: calculate pressure at tube wall, temperature, the distribution of velocity gradient each concentration of component and shearing force by flowing, heat transfer and Mass Transfer Model；By above-mentioned parameter introducing carbon dioxide erosion model, calculate the generating rate of corrosion rate and corrosion product；Corrosion product and the erosion rate of tube wall under action of a fluid is calculated by erosion model；By the corrosion scales correction term of erosion model result of calculation the most again introducing carbon dioxide erosion model, the corrosion rate calculating finally.By importing different ambient parameters, the tube corrosion speed calculating corresponding, select the corrosion rate of safety, determine the safety military service parameter of natural gas well tubing string described in this step.
The concrete calculation procedure of the present invention is as follows:
Adopting, according to Hydrodynamics Theory and natural gas filling, the kinestate related to, use theoretical analysis method to set up mathematical model of flow field, mathematical model of flow field includes heat transfer, flowing, Mass Transfer Model, diffusion of components model, and flow field boundary condition.
(1) mass-conservation equation (equation of continuity) is set up:
In formula, ρ is fluid density, and V is fluid velocity.
(2) momentum conservation equation is set up:
X-direction:
Y direction:
Z direction:
In formula, μ, υ, w are velocity components, and p is fluid isotropism pressure, and τ is the shearing force relevant with fluid viscosity, and f is body force.
(3) energy conservation equation is set up:
In formula, e is thermodynamic energy, and q is the hot-fluid to system transfers, and k is the coefficient of heat conduction.
(4) component delivery diffusion model is set up:
The mass fraction of every kind of material, Y is estimated by the convective-diffusion equation of i-th kind of materiali.Its conservation equation is as follows:
Wherein, ρ is density, and v is diffusional flow speed, JiIt is the diffusion flux of i-th kind of material, R in mixtureiBe chemical reaction only produce speed, SiSpeed is additionally produced for what discrete phase and user-defined source item caused.I=1,2,3 represent CH respectively4、CO2、H2Tri-kinds of materials of O, need to solve the equation of two this forms.
Flow for intraductal turbulance, with following form calculus mass diffusion:
Wherein, Di,mIt is diffusion coefficient, SctIt is turbulent Schmidt number, μtIt is turbulent viscosity power.
Theoretical according to carbon dioxide corrosion, on the basis of the labor to natural gas well corrosion data, set up carbon dioxide corrosion model；In conjunction with erosion corrosion model, set up natural gas injection-production well note and adopt the erosion-electrochemical corrosion mathematical model coupling of process.Carbon dioxide corrosion model expression is:
In formula: a, b, d are the parameters determined according to actual corrosion rate, T is temperature,It is CO2Dividing potential drop, pH is dielectric value, CcofIt it is corrosion rate correction factor.VcIt is carbon dioxide corrosion speed.Introduce corrosion scales afterwards corrosion rate is modified by the factor of influence of corrosion rate: Vc'=[βhd(1+c)+α]Vc, in formula: α, β are the product layer modifying factors to corrosion rate, hd is corrosion product layer thickness, and c is corrosion rate correction factor, Vc' it is revised corrosion rate.
(5) theoretical according to erosion corrosion, on the basis of natural gas well note is adopted the labor of data, set up note and adopt the erosion model of process, based on fluid energy losses data, use energy theory of wear to set up erosion model.This model expression is:
Wherein HfIt it is rate of depreciation；α is rate of depreciation coefficient, actual experiment data release；FwBeing shearing force, μ is medium fluid dynamic viscosity.
(6) modeling software Gambit is used to set up the tubing string model of simulated domain, node coordinate data according to each unit of Flow Field Calculation and the set corresponding relation of the block-centered grid data of Flow Field Calculation, be converted into the finite element numerical model needed for Flow Field Calculation by the tubing string grid model that Gambit sets up；
Above-mentioned model is write UDF, and the tubing string model of the foundation in (6) is imported fluent, in fluent software, set border, flow field and initial condition, in fluent, select the flow field simulation calculation model of correspondence according to the flow field model in step one, boundary types and initial condition；And combining the practical situation of injection-production well, the note of input well is adopted data, is set border and the initial condition of model, the temperature in calculating simulation region, pressure, change in flow in fluent；UDF is imported fluent, calculates injection-production well wall erosion speed.
The present invention provide model and method concentrate discuss in the vertical tubing string of natural gas injection-production well, with gas phase as continuous phase, liquid phase be discrete phase natural gas transmission during the erosion-electrochemical corrosion coupling to tube wall.In this process medium containing liquid fraction less than 1%, flow velocity is less than 25m/s.And using computer numerical simulation to calculate, result of calculation is more identical with actual Corrosion results, it is possible to provide Technical Reference for taking the natural gas well tubing string safety of carbon dioxide and aqueous water.
The part not described in detail in present embodiment or computational methods belong to the known conventional means of the industry, describe the most one by one.Exemplified as above is only the illustration to the present invention, is not intended that the restriction to protection scope of the present invention, within the every and same or analogous design of the present invention belongs to protection scope of the present invention.
Claims (10)
1. the natural gas filling under erosion-carbon dioxide corrosion coupling adopts well casing post corrosion rate
Determination method, it is characterised in that comprise the steps:
Step one: adopt, according to Hydrodynamics Theory and natural gas filling, the kinestate related to, set up each group
Point heat transfer, flow and diffusion mathematical model, calculate pressure at tube wall, temperature, velocity gradient, each group
Divide concentration distribution and shearing force；
Step 2: theoretical according to carbon dioxide corrosion, at the labor to gas well tube corrosion data
On the basis of, set up carbon dioxide corrosion model, determine corrosion scales during carbon dioxide corrosion
For the impact of Electrochemical corrosion rate under this environment, introduce the impact on corrosion rate of the corrosion layer thickness
The factor；
Step 3: theoretical according to erosive wear, on the basis of natural gas well note is adopted the labor of data,
Set up note and adopt the erosion model of process, based on fluid energy losses data, use energy abrasion reason
Opinion sets up erosion model, and determines that scour process is to corrosion scales and tube wall matrix erosive wear speed
Coefficient；
Step 4: each model described in above step one to step 3 is carried out coupling and calculates, calculate pipe
In temperature, pressure, the inlet flow rate impact on corrosion rate, determine the peace of natural gas well tubing string
Entirely it is on active service parameter.
Natural under a kind of erosion-carbon dioxide corrosion coupling the most according to claim 1
The determination method of gas injection-production well tube corrosion speed, it is characterised in that flow described in step one,
Heat transfer model uses hydrodynamics N-S Equation for Calculating；It is public that drop motion in the gas flow introduces Wu drag force
Formula and Newton's second law calculate；Material diffusion in the gas flow uses Convection-Diffusion Model to calculate；Logical
Cross the common calculating of above-mentioned model, pressure at tube wall, temperature, velocity gradient, each component can be obtained
Concentration distribution and shearing force.
Natural under a kind of erosion-carbon dioxide corrosion coupling the most according to claim 1
The determination method of gas injection-production well tube corrosion speed, it is characterised in that the dioxy described in step 2
Change carbon corrosion model as follows:
In formula: the corrected parameter of a, b, d corrosion rate, T is temperature,It is CO2Dividing potential drop, pH is to be situated between
Matter value, CcofIt it is corrosion rate correction factor；VcIt is carbon dioxide corrosion speed；Then introduce corrosion to produce
Corrosion rate is modified by nitride layer by the factor of influence of corrosion rate: V 'c=[βhd(1+c)+α]Vc,
In formula: α, β are the product layer modifying factors to corrosion rate, hd is corrosion product layer thickness, and c is
Corrosion rate correction factor, V 'cIt it is revised corrosion rate.
Natural under a kind of erosion-carbon dioxide corrosion coupling the most according to claim 3
The determination method of gas injection-production well tube corrosion speed, it is characterised in that described carbon dioxide corrosion model
A therein, b, d are to substitute into, according to actual corrosion rate, the parameter that model determines；α, β are real by setting up
Border corrosion rate and corrosion scales thickness relationship obtain.
Natural under a kind of erosion-carbon dioxide corrosion coupling the most according to claim 1
The determination method of gas injection-production well tube corrosion speed, it is characterised in that described in step 3 according to punching
The erosion model that brush wear theory is set up is as follows:
Wherein HfIt it is rate of depreciation；α is rate of depreciation coefficient；FwBeing shearing force, μ is medium fluid
Dynamic viscosity.
Natural under a kind of erosion-carbon dioxide corrosion coupling the most according to claim 5
The determination method of gas injection-production well tube corrosion speed, it is characterised in that described erosion model α therein is
The parameter that model determines is substituted into according to actual erosion rate.
Natural under a kind of erosion-carbon dioxide corrosion coupling the most according to claim 1
The determination method of gas injection-production well tube corrosion speed, it is characterised in that coupling described in step 4 calculates
Method is: calculate pressure at tube wall, temperature, speed ladder by flowing, heat transfer and Mass Transfer Model
Spend the distribution of each concentration of component and shearing force；By above-mentioned parameter introducing carbon dioxide erosion model, calculate
Go out the generating rate of corrosion rate and corrosion product；The effect at fluid is calculated by erosion model
Lower corrosion product and the erosion rate of tube wall；Erosion model result of calculation is imported titanium dioxide the most again
The corrosion scales correction term of carbon corrosion model, the corrosion rate calculating finally.
Natural under a kind of erosion-carbon dioxide corrosion coupling the most according to claim 1
The determination method of gas injection-production well tube corrosion speed, it is characterised in that join by importing different environment
Number, the tube corrosion speed calculating corresponding, select the corrosion rate of safety, determine described in step 4
The safety military service parameter of natural gas well tubing string.
Natural under a kind of erosion-carbon dioxide corrosion coupling the most according to claim 1
The determination method of gas injection-production well tube corrosion speed, it is characterised in that the heat transfer described in step one,
Flowing solves employing fluent computed in software with diffusion mathematical model；And carbon dioxide corrosion, wash away
Wear model uses the UDF User-Defined Functions of fluent software to carry out coupling and calculates.
Natural under a kind of erosion-carbon dioxide corrosion coupling the most according to claim 9
The determination method of gas injection-production well tube corrosion speed, it is characterised in that use Fluent software, by sky
By electrochemical corrosion-erosion corrosion coupling mechanism model write UDF after so gas well tubing string model imports, will
Pressure, concentration of component, temperature and flow parameters Input Software in actual environment carry out double precision meter
Calculate and i.e. can get result of calculation.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
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| CN201610304136.0A CN106021659B (en) | 2016-05-10 | 2016-05-10 | Method for determining corrosion rate of natural gas injection and production well pipe column under erosion-carbon dioxide corrosion coupling effect |
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| CN115292986A (en) * | 2022-07-08 | 2022-11-04 | 中国市政工程华北设计研究总院有限公司 | Performance evaluation method of liquefied natural gas air-temperature gasifier |
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