CN117497074A - Corrosion analysis method, device and terminal for pipe column pipeline system of ultra-high sulfur-containing gas field - Google Patents
Corrosion analysis method, device and terminal for pipe column pipeline system of ultra-high sulfur-containing gas field Download PDFInfo
- Publication number
- CN117497074A CN117497074A CN202311417674.7A CN202311417674A CN117497074A CN 117497074 A CN117497074 A CN 117497074A CN 202311417674 A CN202311417674 A CN 202311417674A CN 117497074 A CN117497074 A CN 117497074A
- Authority
- CN
- China
- Prior art keywords
- corrosion
- partial pressure
- model
- coefficient
- gas field
- 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.)
- Pending
Links
- 230000007797 corrosion Effects 0.000 title claims abstract description 199
- 238000005260 corrosion Methods 0.000 title claims abstract description 199
- 238000004458 analytical method Methods 0.000 title claims abstract description 65
- 229910052717 sulfur Inorganic materials 0.000 title claims abstract description 56
- 239000011593 sulfur Substances 0.000 title claims abstract description 55
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 title claims abstract description 54
- 239000007789 gas Substances 0.000 claims abstract description 65
- 239000000243 solution Substances 0.000 claims abstract description 38
- 238000000034 method Methods 0.000 claims abstract description 27
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 27
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 claims abstract description 24
- 229910000037 hydrogen sulfide Inorganic materials 0.000 claims abstract description 24
- 239000007864 aqueous solution Substances 0.000 claims abstract description 11
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 claims description 35
- 229910052739 hydrogen Inorganic materials 0.000 claims description 35
- 239000001257 hydrogen Substances 0.000 claims description 35
- 238000005530 etching Methods 0.000 claims description 24
- 238000005336 cracking Methods 0.000 claims description 14
- 238000004590 computer program Methods 0.000 claims description 13
- 229910000831 Steel Inorganic materials 0.000 claims description 11
- 239000010959 steel Substances 0.000 claims description 11
- 230000000694 effects Effects 0.000 claims description 8
- 238000006243 chemical reaction Methods 0.000 claims description 7
- 239000007787 solid Substances 0.000 claims description 7
- 238000010276 construction Methods 0.000 claims description 5
- 239000008398 formation water Substances 0.000 claims description 5
- 239000000126 substance Substances 0.000 claims description 5
- 238000004090 dissolution Methods 0.000 claims description 4
- 238000006056 electrooxidation reaction Methods 0.000 claims description 4
- 230000004913 activation Effects 0.000 claims description 3
- 230000001186 cumulative effect Effects 0.000 claims description 3
- 230000006872 improvement Effects 0.000 claims description 3
- 230000008092 positive effect Effects 0.000 claims description 3
- 238000001556 precipitation Methods 0.000 claims description 3
- 230000003628 erosive effect Effects 0.000 abstract 1
- 238000005516 engineering process Methods 0.000 description 12
- 238000003860 storage Methods 0.000 description 12
- 238000004891 communication Methods 0.000 description 8
- 238000010586 diagram Methods 0.000 description 6
- 230000008569 process Effects 0.000 description 6
- XEEYBQQBJWHFJM-UHFFFAOYSA-N Iron Chemical compound [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 description 5
- 238000013473 artificial intelligence Methods 0.000 description 5
- 230000015572 biosynthetic process Effects 0.000 description 4
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 4
- 229910002091 carbon monoxide Inorganic materials 0.000 description 3
- 239000007788 liquid Substances 0.000 description 3
- 238000004519 manufacturing process Methods 0.000 description 3
- 238000012544 monitoring process Methods 0.000 description 3
- 238000012545 processing Methods 0.000 description 3
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 2
- 238000010349 cathodic reaction Methods 0.000 description 2
- 230000001413 cellular effect Effects 0.000 description 2
- 238000003487 electrochemical reaction Methods 0.000 description 2
- 230000006870 function Effects 0.000 description 2
- 239000002184 metal Substances 0.000 description 2
- 229910052751 metal Inorganic materials 0.000 description 2
- 239000003345 natural gas Substances 0.000 description 2
- 230000009467 reduction Effects 0.000 description 2
- 238000012549 training Methods 0.000 description 2
- 241000894006 Bacteria Species 0.000 description 1
- VEXZGXHMUGYJMC-UHFFFAOYSA-M Chloride anion Chemical compound [Cl-] VEXZGXHMUGYJMC-UHFFFAOYSA-M 0.000 description 1
- UCKMPCXJQFINFW-UHFFFAOYSA-N Sulphide Chemical compound [S-2] UCKMPCXJQFINFW-UHFFFAOYSA-N 0.000 description 1
- 230000002411 adverse Effects 0.000 description 1
- 238000003491 array Methods 0.000 description 1
- 230000033558 biomineral tissue development Effects 0.000 description 1
- 230000005587 bubbling Effects 0.000 description 1
- 229910002092 carbon dioxide Inorganic materials 0.000 description 1
- 239000001569 carbon dioxide Substances 0.000 description 1
- 239000003054 catalyst Substances 0.000 description 1
- 238000004140 cleaning Methods 0.000 description 1
- 238000005536 corrosion prevention Methods 0.000 description 1
- 238000013135 deep learning Methods 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 238000001514 detection method Methods 0.000 description 1
- 238000011156 evaluation Methods 0.000 description 1
- 239000012530 fluid Substances 0.000 description 1
- 239000003112 inhibitor Substances 0.000 description 1
- 230000003993 interaction Effects 0.000 description 1
- 229910052742 iron Inorganic materials 0.000 description 1
- 238000010801 machine learning Methods 0.000 description 1
- 230000003211 malignant effect Effects 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000003058 natural language processing Methods 0.000 description 1
- 230000003287 optical effect Effects 0.000 description 1
- 239000002245 particle Substances 0.000 description 1
- 238000002161 passivation Methods 0.000 description 1
- 230000000737 periodic effect Effects 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 239000012071 phase Substances 0.000 description 1
- 230000001737 promoting effect Effects 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 229920006395 saturated elastomer Polymers 0.000 description 1
- 238000001179 sorption measurement Methods 0.000 description 1
- 239000000758 substrate Substances 0.000 description 1
- 238000012360 testing method Methods 0.000 description 1
Classifications
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N17/00—Investigating resistance of materials to the weather, to corrosion, or to light
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F30/00—Computer-aided design [CAD]
- G06F30/20—Design optimisation, verification or simulation
-
- G—PHYSICS
- G16—INFORMATION AND COMMUNICATION TECHNOLOGY [ICT] SPECIALLY ADAPTED FOR SPECIFIC APPLICATION FIELDS
- G16C—COMPUTATIONAL CHEMISTRY; CHEMOINFORMATICS; COMPUTATIONAL MATERIALS SCIENCE
- G16C20/00—Chemoinformatics, i.e. ICT specially adapted for the handling of physicochemical or structural data of chemical particles, elements, compounds or mixtures
- G16C20/10—Analysis or design of chemical reactions, syntheses or processes
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F2113/00—Details relating to the application field
- G06F2113/08—Fluids
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F2113/00—Details relating to the application field
- G06F2113/14—Pipes
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F2119/00—Details relating to the type or aim of the analysis or the optimisation
- G06F2119/08—Thermal analysis or thermal optimisation
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F2119/00—Details relating to the type or aim of the analysis or the optimisation
- G06F2119/14—Force analysis or force optimisation, e.g. static or dynamic forces
Abstract
The embodiment of the invention discloses a corrosion analysis method, a corrosion analysis device and a corrosion analysis terminal for a pipe column system of an ultra-high sulfur-containing gas field, wherein the method comprises the steps of converting H2S/CO2 partial pressure into partial pressure coefficients and constructing a relation model; taking the concentration as an acidity coefficient, and constructing a stratum water solution corrosion model; according to the relation model and the stratum aqueous solution corrosion model, an original hydrogen sulfide corrosion prediction model is improved, and a corrosion rate prediction model is obtained; and carrying out corrosion analysis on the pipe column pipeline system of the ultra-high sulfur-containing gas field by using a corrosion rate prediction model. And constructing an erosion rate prediction model conforming to the corrosion of the data characteristics through the relation model and the stratum aqueous solution corrosion model, so that the corrosion analysis result is more accurate and reliable.
Description
Technical Field
The invention relates to the technical field of pipeline risk evaluation, in particular to a corrosion analysis method, a corrosion analysis device, a corrosion analysis chip and a corrosion analysis storage medium for a pipe column pipeline system of an ultra-high sulfur-containing gas field.
Background
The high sulfur-containing gathering and transportation pipeline has the characteristics of ' high hydrogen sulfide, high carbon dioxide, high water, high chloride ion, high mineralization degree, low pH value ', five high-low ' and strong corrosiveness, can generate Uniform Corrosion (UC), pitting Corrosion (PC), hydrogen Bubbling (HB), hydrogen Induced Cracking (HIC), stress-oriented hydrogen induced cracking (SOHIC), hydrogen Embrittlement (HE), sulfide Stress Corrosion Cracking (SSCC), hydrogen induced ladder cracking (HISC) and the like, and the anode iron is dissolved in the electrochemical reaction process to cause comprehensive corrosion or local corrosion, and is represented by local corrosion damage such as metal drill pipes, oil pipes, sleeves, metal facilities, pipeline wall thickness reduction or pitting corrosion perforation and the like, and various corrosion forms mutually promote to finally lead to material cracking and initiate a large number of malignant accidents.
At present, corrosion prevention of the high-sulfur concentration and transportation pipeline is mainly carried out from three aspects of corrosion monitoring, corrosion rate prediction and experience judgment. Corrosion monitoring is mainly to monitor the corrosion condition of a pipeline body and the corrosion of a medium through monitoring equipment, and the corrosion condition of a reaction pipeline is detected by the related technology, which is disclosed in 202111668023. X, and the temperature and H are detected by the related technology 2 S partial pressure, CO 2 Partial pressure, pH, moisture content, bacteria, cl - The concentration, solid particles, corrosion inhibitor filling, periodic pipe cleaning, gas flow rate, liquid flow rate, service life, conveying mode, stop conveying times and stratum acidizing operation times are used as the inner corrosion parameters of the pipeline to be evaluated, and the method for evaluating the inner corrosion of the pipeline is realized.
Aiming at the related technology, in the actual scene, the influence of each parameter in a mechanical model and a relation model on the result is not constant, and the hydrogen sulfide corrosion model cannot embody the data characteristic, so that a gathering and transportation pipeline system corrosion analysis method needs to be provided for further research, and the defects of the prior art are overcome.
Disclosure of Invention
Based on the method, the device, the chip and the storage medium for corrosion analysis of the pipe column pipeline system of the ultra-high sulfur-containing gas field, a corrosion rate prediction model conforming to the corrosion of data characteristics is constructed, and the corrosion analysis result is more accurate and reliable.
In a first aspect, a corrosion analysis method for a pipe string system of an ultra-high sulfur gas field is provided, including:
will H 2 S/CO 2 Converting the partial pressure into a partial pressure coefficient, and constructing a relation model;
the partial pressure coefficient comprises a dominant partial pressure coefficient and a secondary partial pressure coefficient, when H 2 S/CO 2 When the partial pressure is within a first preset range, the secondary partial pressure coefficient is 0; when H is 2 S/CO 2 When the partial pressure is within a second preset range, the secondary partial pressure coefficient is larger than 0;
HCO is added to 3 - The concentration is used as an acidity coefficient, and a stratum water solution corrosion model is constructed;
the acidity factor includes a dominant acidity factor and a secondary acidity factor, when HCO 3 - When the concentration is within a third preset range, the secondary acidity coefficient is larger than 0; when HCO 3 - When the concentration is within a fourth preset range, the secondary acidity coefficient is smaller than 0;
according to the relation model and the stratum aqueous solution corrosion model, an original hydrogen sulfide corrosion prediction model is improved, and a corrosion rate prediction model is obtained;
and carrying out corrosion analysis on the pipe column pipeline system of the ultra-high sulfur-containing gas field by the corrosion rate prediction model.
Optionally, the H 2 S/CO 2 Converting the partial pressure into a partial pressure coefficient, and constructing a relation model, wherein the method comprises the following steps:
therein, lnv corr1 For the hydrogen etch rate, a is the secondary partial pressure coefficient,is H 2 A limiting value of the influence of solid substance precipitation on the hydrogen etching rate under the S partial pressure; b is the dominant partial pressure coefficient, ">Is H 2 S partial pressure HS - Concentration versus hydrogen etch rateLimit value of influence; />Is CO 2 Limiting the influence of partial pressure on the hydrogen etching rate; />Is the limit value of the influence of temperature on the hydrogen etching rate, D is a coefficient, E a The reaction activation energy of the steel is T is the temperature, and R is the universal gas constant; elnv is the limit value of the influence of the flow rate on the hydrogen etching rate, E is the coefficient, and C is the constant.
Alternatively, HCO is used 3 - Converting the concentration into an acidity coefficient, and constructing a stratum water solution corrosion model, wherein the method comprises the following steps of:
wherein M is the secondary acidity coefficient,is HCO in stratum water solution 3 - A limit value at which the concentration has a positive effect on the corrosion rate; e is the dominant acidity coefficient, ">Is HCO in stratum water solution 3 - A basal limit value for the effect of concentration on the corrosion rate; f is less than 0, flnV Ca Is>Limiting the effect of concentration on the corrosion rate.
Optionally, before the corrosion rate prediction model is used for carrying out corrosion analysis on the pipe system of the ultra-high sulfur gas field pipe column, the method comprises the following steps:
h for detecting pipe column pipeline system of ultrahigh sulfur-containing gas field 2 S/CO 2 The actual partial pressure;
obtaining the pipe column pipe of the ultra-high sulfur-containing gas fieldStratum water solution sample of system and HCO detection based on stratum water solution sample 3 - Actual concentration;
according to the H 2 S/CO 2 Actual partial pressure and the HCO 3 - And (3) setting the actual concentration and the internal corrosion parameter of the corrosion rate prediction model.
Optionally, performing corrosion analysis on the ultra-high sulfur gas field tubular column pipeline system through the corrosion rate prediction model, including:
the corrosion rate prediction model outputs a maximum corrosion rate;
calculating a maximum cumulative thinning amount according to the maximum corrosion rate;
and when the maximum accumulated thinning amount is larger than a first preset value, slightly corroding the pipe system of the extra-high sulfur-containing gas field pipe column.
Optionally, the original hydrogen sulfide corrosion prediction model comprises a solution corrosion analysis part and a gas corrosion analysis part;
the solution corrosion analysis part comprises an electrochemical corrosion relation model, an anodic dissolution type hydrogen sulfide stress corrosion cracking model and a hydrogen induced cracking type hydrogen sulfide stress corrosion cracking model;
the gas corrosion analysis part comprises hydrogen corrosion rate, temperature, pressure and H 2 S, a relation model between partial pressure and flow speed;
the improved raw hydrogen sulfide corrosion prediction model comprises:
modifying hydrogen etching rate and temperature, pressure and H 2 And S partial pressure, flow speed and formation water solution corrosion increase.
Optionally, the first preset range is greater than the second preset range; the third preset range is smaller than the fourth preset range.
In a second aspect, there is provided a corrosion analysis device for a pipe string system of an ultra-high sulfur gas field, comprising:
a relation model construction module for constructing H 2 S/CO 2 Converting the partial pressure into a partial pressure coefficient, and constructing a relation model;
the said divisionThe pressure coefficient includes a dominant partial pressure coefficient and a secondary partial pressure coefficient, when H 2 S/CO 2 When the partial pressure is within a first preset range, the secondary partial pressure coefficient is 0; when H is 2 S/CO 2 When the partial pressure is within a second preset range, the secondary partial pressure coefficient is larger than 0;
formation water solution corrosion model construction module for HCO 3 - The concentration is used as an acidity coefficient, and a stratum water solution corrosion model is constructed;
the acidity factor includes a dominant acidity factor and a secondary acidity factor, when HCO 3 - When the concentration is within a third preset range, the secondary acidity coefficient is larger than 0; when HCO 3 - When the concentration is within a fourth preset range, the secondary acidity coefficient is smaller than 0;
the model improvement module is used for improving an original hydrogen sulfide corrosion prediction model according to the relation model and the stratum aqueous solution corrosion model to obtain a corrosion rate prediction model;
and the corrosion analysis module is used for carrying out corrosion analysis on the pipe column pipeline system of the ultra-high sulfur-containing gas field through the corrosion rate prediction model.
In a third aspect, there is provided a chip comprising a first processor for calling and running a computer program from a first memory, such that a device on which the chip is mounted performs the steps of corrosion analysis of ultra high sulfur gas field tubular string piping systems according to any one of claims 1 to 7.
In a fourth aspect, a terminal is provided, which comprises a second memory, a second processor and a computer program stored in the second memory and capable of running on the second processor, wherein the second processor executes the computer program to implement the steps of the corrosion analysis method for the ultra-high sulfur gas field tubular column pipeline system as introduced above.
According to the corrosion analysis method, the corrosion analysis device, the corrosion analysis chip and the corrosion analysis storage medium for the ultra-high sulfur gas field tubular column pipeline system, the corrosion rate prediction model conforming to the data characteristic corrosion is constructed through the relation model and the stratum aqueous solution corrosion model, so that the corrosion analysis result is more accurate and reliable.
Drawings
In order to more clearly illustrate the technical solutions of the embodiments of the present invention, the drawings that are needed in the description of the embodiments will be briefly described below, it being obvious that the drawings in the following description are only some embodiments of the present invention, and that other drawings may be obtained according to these drawings without inventive effort for a person skilled in the art.
FIG. 1 is a basic flow diagram of a corrosion analysis method for a pipe string system of an ultra-high sulfur gas field according to an embodiment of the present invention;
FIG. 2 is a basic structural block diagram of a corrosion analysis device for a pipe column pipeline system of an ultra-high sulfur gas field according to an embodiment of the invention;
fig. 3 is a basic structural block diagram of a terminal according to an embodiment of the present invention.
Detailed Description
In order to enable those skilled in the art to better understand the present invention, the following description will make clear and complete descriptions of the technical solutions according to the embodiments of the present invention with reference to the accompanying drawings.
In some of the flows described in the specification and claims of the present invention and in the foregoing figures, a plurality of operations occurring in a particular order are included, but it should be understood that the operations may be performed out of order or performed in parallel, with the order of operations such as 101, 102, etc., being merely used to distinguish between the various operations, the order of the operations themselves not representing any order of execution. In addition, the flows may include more or fewer operations, and the operations may be performed sequentially or in parallel. It should be noted that, the descriptions of "first" and "second" herein are used to distinguish different messages, devices, modules, etc., and do not represent a sequence, and are not limited to the "first" and the "second" being different types.
The following description of the embodiments of the present invention will be made clearly and completely with reference to the accompanying drawings, in which it is apparent that the embodiments described are only some embodiments of the present invention, but not all embodiments. All other embodiments, which can be made by a person skilled in the art without any inventive effort, are intended to be within the scope of the present invention based on the embodiments of the present invention.
The embodiment of the application can acquire and process the related data based on the artificial intelligence technology. Among them, artificial intelligence (AI: artificial Intelligence) is a theory, method, technique and application system that simulates, extends and expands human intelligence using a digital computer or a machine controlled by a digital computer, perceives the environment, acquires knowledge and uses the knowledge to obtain the best result.
Artificial intelligence infrastructure technologies generally include technologies such as sensors, dedicated artificial intelligence chips, cloud computing, distributed storage, big data processing technologies, operation/interaction systems, mechatronics, and the like. The artificial intelligence software technology mainly comprises a computer vision technology, a robot technology, a biological recognition technology, a voice processing technology, a natural language processing technology, machine learning/deep learning and other directions.
Referring specifically to fig. 1, fig. 1 is a schematic diagram of a basic flow chart of a corrosion analysis method for a pipe string system of an ultra-high sulfur gas field according to the present embodiment.
As shown in fig. 1, the corrosion analysis method for the pipe column system of the ultra-high sulfur gas field comprises the following steps:
s101, H 2 S/CO 2 Converting the partial pressure into a partial pressure coefficient, and constructing a relation model;
the partial pressure coefficient comprises a dominant partial pressure coefficient and a secondary partial pressure coefficient, when H 2 S/CO 2 When the partial pressure is within a first preset range, the secondary partial pressure coefficient is 0; when H is 2 S/CO 2 And when the partial pressure is within a second preset range, the secondary partial pressure coefficient is larger than 0.
In the above step S101, the formula of the relationship model is expressed as:
therein, lnv corr1 At a hydrogen etching rate, A is a secondary partial pressureThe coefficient of the,is H 2 A limiting value of the influence of solid substance precipitation on the hydrogen etching rate under the S partial pressure; b is the dominant partial pressure coefficient, ">Is H 2 S partial pressure HS - A limit value of the concentration effect on the hydrogen etching rate; />Is CO 2 Limiting the influence of partial pressure on the hydrogen etching rate; />Is the limit value of the influence of temperature on the hydrogen etching rate, D is a coefficient, E a The reaction activation energy of the steel is T is the temperature, and R is the universal gas constant; elnv is the limit value of the influence of the flow rate on the hydrogen etching rate, E is the coefficient, and C is the constant.
The limit value is obtained by establishing a corresponding corrosion model and performing model training by using historical data.
The relation model is hydrogen etching rate, temperature, pressure and H 2 S partial pressure and flow velocity. The embodiment of the invention is improved, and the principle is as follows:
in practical applications, natural gas fluids contain gas phase, water, solid particulates, etc. during natural gas production. The water content of the gas phase is in a saturated state, once water drops are precipitated on the surface of the steel body to form a liquid film, H 2 S、CO 2 The equal corrosive gas is dissolved in the liquid drop to generate electrochemical reaction, H 2 S and CO 2 Ionizable to produce H + ，H + Further reduction to H 2 The cathodic reaction is shown by the following formula:
H 2 O (di) →H 2 O (aq)
CO 2 (g)+H 2 O(l)→H 2 CO 3 (aq)
2H + +2e→H 2
di, aq, g, l, ads represent the status of the respective substances.
The anode is mainly dissolved Fe, and the reaction process is shown as the following formula:
H 2 S、CO 2 all of the dissolution of (C) increases H + The concentration is reduced, the pH value is lowered, and the electrochemical corrosion process is promoted. But HS is provided with - Ratio ofHas better chemical adsorption to the surface of steel substrate, can accelerate corrosion, but can inhibit other corrosive components (such as H) 2 CO 3 ,/>) Reacts with Fe. Thus, feS and FeS 1-x After reaching the solubility product, the corrosion product is more likely to be separated out and covered on the surface of the steel body to form granular, loose and porous corrosion products, and the corrosion product is dissolved in H 2 S/CO 2 When the partial pressure is relatively high, feCO 3 Reaching the solubility product and separating out a small amount of FeCO 3 However, a dense film layer cannot be formed, so that a good protection effect on the steel body is difficult to achieve, and corrosion products are generated and reacted as shown in the formula.
Production of the product:
Fe 2+ +S 2- →FeS
based on this, embodiments of the present invention contemplate that the following is true for H 2 S/CO 2 Under the condition of high partial pressure, solid matters are precipitated, namely FeS and FeS 1-x 、FeCO 3 Impact on hydrogen etch rate.
S102, HCO is added 3 - The concentration is used as an acidity coefficient, and a stratum water solution corrosion model is constructed;
the acidity factor includes a dominant acidity factor and a secondary acidity factor, when HCO 3 - When the concentration is within a third preset range, the secondary acidity coefficient is larger than 0; when HCO 3 - When the concentration is within a fourth preset range, the secondary acidity coefficient is smaller than 0;
in the above step S102, the formula of the formation aqueous solution corrosion model is expressed as:
wherein M is the secondary acidity coefficient,is HCO in stratum water solution 3 - A limit value at which the concentration has a positive effect on the corrosion rate; e is the dominant acidity coefficient, ">Is HCO in stratum water solution 3 - A basal limit value for the effect of concentration on the corrosion rate; f is less than 0, flnV Ca Is>Limiting the effect of concentration on the corrosion rate.
The limit value is obtained by establishing a corresponding corrosion model and performing model training by using historical data.
In practice, cl in the aqueous formation solution is simulated - 、Etc. can affect the etching process. Cl - When the radius is smaller and the permeability is strong and the surface of the steel body is a compact passivation film, the closed battery is easy to be formed and further causes local corrosion, but the Cl in the stratum aqueous solution is simulated - The concentration is small and the product is loose and porous, so Cl - The corrosion influence on steel is small, and the sample presents uniform corrosion. />On one hand, the catalyst can be used as a cathode depolarizer to directly participate in cathode reaction so as to accelerate the corrosion process, as shown in a formula (8); on the other hand (S)>Is involved in the cathodic reaction and is produced->When->When the concentration is large, compact FeCO is generated 3 The product film can block corrosion process, and according to XRD test result, the products are mainly FeS and FeS 1-x Thus +.>Plays a role in promoting steel corrosion. In solution +.>Can be combined with-> Reaction to produce CaSO 4 And CaCO (CaCO) 3 Scale deposits on the surface of the steel body can slow down corrosion to some extent.
Based on the method, the embodiment of the invention constructs a stratum water solution corrosion model and improves an original hydrogen sulfide corrosion prediction model.
In this embodiment of the present invention, the first preset range is greater than the second preset range, which indicates a higher H 2 S/CO 2 Under the partial pressure condition, solid matters are separated out to cause the speed influence on hydrogen etching; the third preset range being smaller than the fourth preset range, indicating a higher HCO 3 - At this concentration, the corrosion rate is adversely affected.
S103, an original hydrogen sulfide corrosion prediction model is improved according to the relation model and the stratum water solution corrosion model, and a corrosion rate prediction model is obtained.
In the step S103, the original hydrogen sulfide corrosion prediction model includes a solution corrosion analysis portion and a gas corrosion analysis portion;
the solution corrosion analysis part comprises an electrochemical corrosion relation model, an anodic dissolution type hydrogen sulfide stress corrosion cracking model and a hydrogen induced cracking type hydrogen sulfide stress corrosion cracking model;
gas decayThe etching analysis part comprises hydrogen etching rate, temperature, pressure and H 2 S, a relation model between partial pressure and flow speed;
based thereon, the improved raw hydrogen sulfide corrosion prediction model comprises:
modifying hydrogen etching rate and temperature, pressure and H 2 And S partial pressure, flow speed and formation water solution corrosion increase.
S104, performing corrosion analysis on the pipe column and pipe system of the ultra-high sulfur-containing gas field through the corrosion rate prediction model.
Before the step S104, the method includes:
h for detecting pipe column pipeline system of ultrahigh sulfur-containing gas field 2 S/CO 2 The actual partial pressure;
obtaining a stratum water solution sample of a pipe column pipeline system of the ultra-high sulfur gas field, and detecting HCO based on the stratum water solution sample 3 - Actual concentration;
according to the H 2 S/CO 2 Actual partial pressure and the HCO 3 - And (3) setting the actual concentration and the internal corrosion parameter of the corrosion rate prediction model.
The corrosion rate prediction model is used for carrying out corrosion analysis on the pipe column and pipe system of the ultra-high sulfur-containing gas field, and the method comprises the following steps:
the corrosion rate prediction model outputs a maximum corrosion rate;
calculating a maximum cumulative thinning amount according to the maximum corrosion rate;
and when the maximum accumulated thinning amount is larger than a first preset value, slightly corroding the pipe system of the extra-high sulfur-containing gas field pipe column.
As shown in fig. 2, to solve the above technical problem, an embodiment of the present invention further provides a corrosion analysis device 20 for a pipe string system of an ultra-high sulfur gas field, including:
a relational model construction module 21 for constructing H 2 S/CO 2 Converting the partial pressure into a partial pressure coefficient, and constructing a relation model;
the partial pressure coefficient comprises a dominant partial pressure coefficient and a secondary partial pressure coefficient, when H 2 S/CO 2 Partial pressure atWhen the secondary partial pressure coefficient is within a first preset range, the secondary partial pressure coefficient is 0; when H is 2 S/CO 2 When the partial pressure is within a second preset range, the secondary partial pressure coefficient is larger than 0;
formation aqueous solution corrosion model building block 22 for the production of HCO 3 - The concentration is used as an acidity coefficient, and a stratum water solution corrosion model is constructed;
the acidity factor includes a dominant acidity factor and a secondary acidity factor, when HCO 3 - When the concentration is within a third preset range, the secondary acidity coefficient is larger than 0; when HCO 3 - When the concentration is within a fourth preset range, the secondary acidity coefficient is smaller than 0;
a model improvement module 23, configured to improve an original hydrogen sulfide corrosion prediction model according to the relationship model and the formation aqueous solution corrosion model, to obtain a corrosion rate prediction model;
and the corrosion analysis module 24 is used for carrying out corrosion analysis on the pipe column pipeline system of the ultra-high sulfur-containing gas field through the corrosion rate prediction model.
In order to solve the above technical problems, the embodiment of the present invention further provides a chip, where the chip may be a general-purpose processor or a special-purpose processor. The chip comprises a processor, and the processor is used for supporting the terminal to execute the related steps, such as calling and running a computer program from a memory, so that equipment provided with the chip executes the relevant steps to realize the corrosion analysis method of the ultra-high sulfur gas field tubular column pipeline system in the various embodiments.
Optionally, in some examples, the chip further includes a transceiver, where the transceiver is controlled by the processor, and is configured to support the terminal to perform the relevant steps to implement the method for analyzing corrosion of the pipe system of the extra-high sulfur gas field pipe string in the embodiments described above.
Optionally, the chip may further comprise a storage medium.
It should be noted that the chip may be implemented using the following circuits or devices: one or more field programmable gate arrays (field programmable gate array, FPGA), programmable logic devices (programmablelogic device, PLD), controllers, state machines, gate logic, discrete hardware components, any other suitable circuit or combination of circuits capable of performing the various functions described throughout this application.
The invention also provides a terminal comprising a memory, a processor and a computer program stored in the memory and capable of running on the processor, wherein the processor executes the computer program to realize the steps of the corrosion analysis method of the ultra-high sulfur gas field tubular column system according to any one of claims 1 to 7.
Referring specifically to fig. 3, fig. 3 is a basic block diagram illustrating a terminal including a processor, a nonvolatile storage medium, a memory, and a network interface connected by a system bus. The nonvolatile storage medium of the terminal stores an operating system, a database and a computer readable instruction, the database can store a control information sequence, and when the computer readable instruction is executed by a processor, the processor can realize an ultrahigh sulfur-containing gas field pipe column pipeline system corrosion analysis method. The processor of the terminal is operative to provide computing and control capabilities supporting the operation of the entire terminal. The memory of the terminal can store computer readable instructions which, when executed by the processor, can cause the processor to execute a corrosion analysis method for the ultra-high sulfur gas field tubular column pipeline system. The network interface of the terminal is used for connecting and communicating with the terminal. It will be appreciated by those skilled in the art that the structures shown in the drawings are block diagrams of only some of the structures associated with the aspects of the present application and are not intended to limit the terminals to which the aspects of the present application may be applied, and that a particular terminal may include more or less components than those shown, or may combine some of the components, or have a different arrangement of components.
As used herein, a "terminal" or "terminal device" includes both a device of a wireless signal receiver having no transmitting capability and a device of receiving and transmitting hardware having electronic devices capable of performing two-way communication over a two-way communication link, as will be appreciated by those skilled in the art. Such an electronic device may include: a cellular or other communication device having a single-line display or a multi-line display or a cellular or other communication device without a multi-line display; a PCS (Personal Communications Service, personal communication system) that may combine voice, data processing, facsimile and/or data communication capabilities; a PDA (Personal Digital Assistant ) that can include a radio frequency receiver, pager, internet/intranet access, web browser, notepad, calendar and/or GPS (Global Positioning System ) receiver; a conventional laptop and/or palmtop computer or other appliance that has and/or includes a radio frequency receiver. As used herein, "terminal," "terminal device" may be portable, transportable, installed in a vehicle (aeronautical, maritime, and/or land-based), or adapted and/or configured to operate locally and/or in a distributed fashion, to operate at any other location(s) on earth and/or in space. The "terminal" and "terminal device" used herein may also be a communication terminal, a network access terminal, and a music/video playing terminal, for example, may be a PDA, a MID (Mobile Internet Device ), and/or a mobile phone with a music/video playing function, and may also be a smart tv, a set top box, and other devices.
The invention also provides a storage medium storing computer readable instructions that when executed by one or more processors cause the one or more processors to perform the steps of the ultra-high sulfur gas field tubular string system corrosion analysis method of any of the embodiments described above.
The embodiment also provides a computer program which can be distributed on a computer readable medium and executed by a computable device to realize at least one step of the corrosion analysis method of the ultra-high sulfur gas field tubular column pipeline system; and in some cases at least one of the steps shown or described may be performed in a different order than that described in the above embodiments.
The present embodiment also provides a computer program product comprising computer readable means having stored thereon a computer program as shown above. The computer readable means in this embodiment may comprise a computer readable storage medium as shown above.
Those skilled in the art will appreciate that implementing all or part of the above-described methods in accordance with the embodiments may be accomplished by way of a computer program stored in a computer-readable storage medium, which when executed, may comprise the steps of the embodiments of the methods described above. The storage medium may be a nonvolatile storage medium such as a magnetic disk, an optical disk, a Read-Only Memory (ROM), or a random access Memory (Random Access Memory, RAM).
It should be understood that, although the steps in the flowcharts of the figures are shown in order as indicated by the arrows, these steps are not necessarily performed in order as indicated by the arrows. The steps are not strictly limited in order and may be performed in other orders, unless explicitly stated herein. Moreover, at least some of the steps in the flowcharts of the figures may include a plurality of sub-steps or stages that are not necessarily performed at the same time, but may be performed at different times, the order of their execution not necessarily being sequential, but may be performed in turn or alternately with other steps or at least a portion of the other steps or stages.
The technical features of the above-described embodiments may be arbitrarily combined, and all possible combinations of the technical features in the above-described embodiments are not described for brevity of description, however, as long as there is no contradiction between the combinations of the technical features, they should be considered as the scope of the description.
The foregoing examples illustrate only a few embodiments of the invention and are described in detail herein without thereby limiting the scope of the invention. It should be noted that it will be apparent to those skilled in the art that several variations and modifications can be made without departing from the spirit of the invention, which are all within the scope of the invention. Accordingly, the scope of protection of the present invention is to be determined by the appended claims.
Claims (10)
1. The corrosion analysis method for the pipe column pipeline system of the ultra-high sulfur gas field is characterized by comprising the following steps of:
will H 2 S/CO 2 Converting the partial pressure into a partial pressure coefficient, and constructing a relation model;
the partial pressure coefficient comprises a dominant partial pressure coefficient and a secondary partial pressure coefficient, when H 2 S/CO 2 When the partial pressure is within a first preset range, the secondary partial pressure coefficient is 0; when H is 2 S/CO 2 When the partial pressure is within a second preset range, the secondary partial pressure coefficient is larger than 0;
HCO is added to 3 - The concentration is used as an acidity coefficient, and a stratum water solution corrosion model is constructed;
the acidity factor includes a dominant acidity factor and a secondary acidity factor, when HCO 3 - When the concentration is within a third preset range, the secondary acidity coefficient is larger than 0; when HCO 3 - When the concentration is within a fourth preset range, the secondary acidity coefficient is smaller than 0;
according to the relation model and the stratum aqueous solution corrosion model, an original hydrogen sulfide corrosion prediction model is improved, and a corrosion rate prediction model is obtained;
and carrying out corrosion analysis on the pipe column pipeline system of the ultra-high sulfur-containing gas field by the corrosion rate prediction model.
2. The method for analyzing corrosion of a tubular string system of an ultra-high sulfur gas field according to claim 1, wherein said H is 2 S/CO 2 Converting the partial pressure into a partial pressure coefficient, and constructing a relation model, wherein the method comprises the following steps:
wherein lnv corr1 For hydrogen etching rate, A is the secondary partial pressure coefficient, alnP H2S Is H 2 A limiting value of the influence of solid substance precipitation on the hydrogen etching rate under the S partial pressure; b is the dominant partial pressure coefficient,is H 2 S partial pressure HS - A limit value of the concentration effect on the hydrogen etching rate; />Is CO 2 Limiting the influence of partial pressure on the hydrogen etching rate; />Is the limit value of the influence of temperature on the hydrogen etching rate, D is a coefficient, E a The reaction activation energy of the steel is T is the temperature, and R is the universal gas constant; elnv is the limit value of the influence of the flow rate on the hydrogen etching rate, E is the coefficient, and C is the constant.
3. The method for analyzing corrosion of a tubular column pipeline system of an ultra-high sulfur gas field according to claim 1, wherein HCO is obtained by 3 - Converting the concentration into an acidity coefficient, and constructing a stratum water solution corrosion model, wherein the method comprises the following steps of:
wherein M is the secondary acidity coefficient,is HCO in stratum water solution 3 - A limit value at which the concentration has a positive effect on the corrosion rate; e is the dominant acidity coefficient, ">Is HCO in stratum water solution 3 - Influence of concentration on corrosion rateA base limit value; f is less than 0, flnV Ca Is>Limiting the effect of concentration on the corrosion rate.
4. The method for analyzing corrosion of a tubular string system of an ultra-high sulfur gas field according to claim 1, comprising, before the analysis of corrosion of the tubular string system of an ultra-high sulfur gas field by the corrosion rate prediction model:
h for detecting pipe column pipeline system of ultrahigh sulfur-containing gas field 2 S/CO 2 The actual partial pressure;
obtaining a stratum water solution sample of a pipe column pipeline system of the ultra-high sulfur gas field, and detecting HCO based on the stratum water solution sample 3 - Actual concentration;
according to the H 2 S/CO 2 Actual partial pressure and the HCO 3 - And (3) setting the actual concentration and the internal corrosion parameter of the corrosion rate prediction model.
5. The method for analyzing corrosion of a tubular string system of an ultra-high sulfur gas field according to claim 4, wherein the analysis of corrosion of a tubular string system of an ultra-high sulfur gas field by the corrosion rate prediction model comprises:
the corrosion rate prediction model outputs a maximum corrosion rate;
calculating a maximum cumulative thinning amount according to the maximum corrosion rate;
and when the maximum accumulated thinning amount is larger than a first preset value, slightly corroding the pipe system of the extra-high sulfur-containing gas field pipe column.
6. The method for analyzing corrosion of a pipe string system of an ultra-high sulfur gas field according to claim 1, wherein the original hydrogen sulfide corrosion prediction model comprises a solution corrosion analysis part and a gas corrosion analysis part;
the solution corrosion analysis part comprises an electrochemical corrosion relation model, an anodic dissolution type hydrogen sulfide stress corrosion cracking model and a hydrogen induced cracking type hydrogen sulfide stress corrosion cracking model;
the gas corrosion analysis part comprises hydrogen corrosion rate, temperature, pressure and H 2 S, a relation model between partial pressure and flow speed;
the improved raw hydrogen sulfide corrosion prediction model comprises: modifying hydrogen etching rate and temperature, pressure and H 2 And S partial pressure, flow speed and formation water solution corrosion increase.
7. The ultra-high sulfur gas field tubular string system corrosion analysis method according to claim 1, wherein the first preset range is greater than the second preset range; the third preset range is smaller than the fourth preset range.
8. An extra-high sulfur gas field tubular column pipeline system corrosion analysis device, which is characterized by comprising:
a relation model construction module for constructing H 2 S/CO 2 Converting the partial pressure into a partial pressure coefficient, and constructing a relation model;
the partial pressure coefficient comprises a dominant partial pressure coefficient and a secondary partial pressure coefficient, when H 2 S/CO 2 When the partial pressure is within a first preset range, the secondary partial pressure coefficient is 0; when H is 2 S/CO 2 When the partial pressure is within a second preset range, the secondary partial pressure coefficient is larger than 0;
formation water solution corrosion model construction module for HCO 3 - The concentration is used as an acidity coefficient, and a stratum water solution corrosion model is constructed;
the acidity factor includes a dominant acidity factor and a secondary acidity factor, when HCO 3 - When the concentration is within a third preset range, the secondary acidity coefficient is larger than 0; when HCO 3 - When the concentration is within a fourth preset range, the secondary acidity coefficient is smaller than 0;
the model improvement module is used for improving an original hydrogen sulfide corrosion prediction model according to the relation model and the stratum aqueous solution corrosion model to obtain a corrosion rate prediction model;
and the corrosion analysis module is used for carrying out corrosion analysis on the pipe column pipeline system of the ultra-high sulfur-containing gas field through the corrosion rate prediction model.
9. A chip, comprising: a first processor for calling and running a computer program from a first memory, so that a device on which the chip is mounted performs the steps of the ultra-high sulfur gas field string tubing corrosion analysis method according to any one of claims 1 to 7.
10. A terminal comprising a second memory, a second processor and a computer program stored in and executable on the second memory, wherein the second processor, when executing the computer program, performs the steps of the ultra-high sulfur gas field tubular string system corrosion analysis method according to any one of claims 1 to 7.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202311417674.7A CN117497074A (en) | 2023-10-30 | 2023-10-30 | Corrosion analysis method, device and terminal for pipe column pipeline system of ultra-high sulfur-containing gas field |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202311417674.7A CN117497074A (en) | 2023-10-30 | 2023-10-30 | Corrosion analysis method, device and terminal for pipe column pipeline system of ultra-high sulfur-containing gas field |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN117497074A true CN117497074A (en) | 2024-02-02 |
Family
ID=89679272
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202311417674.7A Pending CN117497074A (en) | 2023-10-30 | 2023-10-30 | Corrosion analysis method, device and terminal for pipe column pipeline system of ultra-high sulfur-containing gas field |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN117497074A (en) |
Citations (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CA2748378A1 (en) * | 2009-01-19 | 2010-07-22 | Bp Corporation North America Inc. | Method and system for predicting corrosion rates using mechanistic models |
| US20140005995A1 (en) * | 2012-06-29 | 2014-01-02 | Chevron U.S.A. Inc. | Processes and systems for predicting corrosion |
| CN109815595A (en) * | 2019-01-26 | 2019-05-28 | 南智（重庆）能源技术有限公司 | Oil gas field down-hole string and well head gas transmission line hydrogen sulfide corrosion big data analysis method |
| CN112735538A (en) * | 2020-12-09 | 2021-04-30 | 中国电器科学研究院股份有限公司 | Metal atmospheric corrosion rate prediction algorithm based on substance transfer dynamics model |
| CN113761476A (en) * | 2020-06-01 | 2021-12-07 | 中国石油化工股份有限公司 | Refining pipeline corrosion comprehensive prediction method and device based on local detection |
| US20230143519A1 (en) * | 2021-11-11 | 2023-05-11 | Beihang University | Field monitoring electrochemical method for anticorrosion performance of organic coatings in seawater environment |
| WO2023170034A1 (en) * | 2022-03-10 | 2023-09-14 | Shell Internationale Research Maatschappij B.V. | System and method for predicting corrosion rate in a pipe section |
-
2023
- 2023-10-30 CN CN202311417674.7A patent/CN117497074A/en active Pending
Patent Citations (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CA2748378A1 (en) * | 2009-01-19 | 2010-07-22 | Bp Corporation North America Inc. | Method and system for predicting corrosion rates using mechanistic models |
| US20140005995A1 (en) * | 2012-06-29 | 2014-01-02 | Chevron U.S.A. Inc. | Processes and systems for predicting corrosion |
| CN109815595A (en) * | 2019-01-26 | 2019-05-28 | 南智（重庆）能源技术有限公司 | Oil gas field down-hole string and well head gas transmission line hydrogen sulfide corrosion big data analysis method |
| CN113761476A (en) * | 2020-06-01 | 2021-12-07 | 中国石油化工股份有限公司 | Refining pipeline corrosion comprehensive prediction method and device based on local detection |
| CN112735538A (en) * | 2020-12-09 | 2021-04-30 | 中国电器科学研究院股份有限公司 | Metal atmospheric corrosion rate prediction algorithm based on substance transfer dynamics model |
| US20230143519A1 (en) * | 2021-11-11 | 2023-05-11 | Beihang University | Field monitoring electrochemical method for anticorrosion performance of organic coatings in seawater environment |
| WO2023170034A1 (en) * | 2022-03-10 | 2023-09-14 | Shell Internationale Research Maatschappij B.V. | System and method for predicting corrosion rate in a pipe section |
Non-Patent Citations (3)
| Title |
|---|
| 张清;李萍;白真权;: "不同CO_2/H_2S分压下油管钢腐蚀速率预测模型", 焊管, no. 01, 28 January 2006 (2006-01-28), pages 43 - 45 * |
| 朱健军;李岩;王强军;: "徐深气田CO_2腐蚀预测模型的建立", 油气田地面工程, no. 04, 1 April 2013 (2013-04-01), pages 20 - 21 * |
| 邓洪达;李春福;罗平亚;: "含硫气田腐蚀研究现状", 材料保护, no. 03, 15 March 2008 (2008-03-15), pages 58 - 62 * |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| Nešić | Key issues related to modelling of internal corrosion of oil and gas pipelines–A review | |
| Kahyarian et al. | Modeling of uniform CO2 corrosion of mild steel in gas transportation systems: a review | |
| Obot et al. | Electrochemical noise (EN) technique: review of recent practical applications to corrosion electrochemistry research | |
| US8447529B2 (en) | Method and system for predicting corrosion rates using mechanistic models | |
| CN107063991B (en) | Dynamic safety assessment method and device for internal corrosion defects of conveying pipeline | |
| CN103870670B (en) | A kind of tube corrosion degree Forecasting Methodology and device | |
| Nešić et al. | Implementation of a comprehensive mechanistic prediction model of mild steel corrosion in multiphase oil and gas pipelines | |
| Wang et al. | Evolution of corrosion prediction models for oil and gas pipelines: From empirical-driven to data-driven | |
| Moore III | Long-term corrosion processes of iron and steel shipwrecks in the marine environment: A review of current knowledge | |
| Velázquez et al. | Probabilistic and statistical techniques to study the impact of localized corrosion defects in oil and gas pipelines: a review | |
| Sim et al. | Aqueous corrosion testing and neural network modeling to simulate corrosion of supercritical CO2 pipelines in the carbon capture and storage cycle | |
| Imran et al. | Application of artificial intelligence in marine corrosion prediction and detection | |
| CN110186840B (en) | Method for processing damage test data of casing of water injection well | |
| CN117497074A (en) | Corrosion analysis method, device and terminal for pipe column pipeline system of ultra-high sulfur-containing gas field | |
| Dao et al. | A Bayesian approach to assess under-deposit corrosion in oil and gas pipelines | |
| Qin et al. | Quantitative risk assessment of static equipment in petroleum and natural gas processing station based on corrosion-thinning failure degree | |
| Soomro et al. | Deep learning-based reliability model for oil and gas pipeline subjected to stress corrosion cracking: A review and concept | |
| CN115907084A (en) | Method, device, equipment and medium for predicting floating of marine floating object | |
| Guan et al. | Application of probabilistic model in pipeline direct assessment | |
| Paz et al. | Prediction of calcium carbonate scaling in pipes using artificial neural networks | |
| Zimer et al. | Temporal series of micrographs coupled with electrochemical techniques to analyze pitting corrosion of AISI 1040 steel in carbonate and chloride solutions | |
| Shayegani et al. | Modelling of carbon dioxide corrosion of steel with iron carbonate precipitation | |
| CN116912699B (en) | Port oil spill diffusion trend prediction method and system based on image processing | |
| LEIVA-GARCIA et al. | Cellular Automata simulation of corrosion and scaling processes taking place in CO2 saturated solutions | |
| Ribeiro | Annulus CO2-corrosion of high strength steel wires from unbounded flexible pipes |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination |