CN114062243B - Design method of long-acting liquid anti-corrosion layer of multiphase conveying pipeline - Google Patents
Design method of long-acting liquid anti-corrosion layer of multiphase conveying pipeline Download PDFInfo
- Publication number
- CN114062243B CN114062243B CN202111351409.4A CN202111351409A CN114062243B CN 114062243 B CN114062243 B CN 114062243B CN 202111351409 A CN202111351409 A CN 202111351409A CN 114062243 B CN114062243 B CN 114062243B
- Authority
- CN
- China
- Prior art keywords
- oil
- water
- corrosion
- carbon steel
- storage surface
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Active
Links
- 238000005260 corrosion Methods 0.000 title claims abstract description 88
- 238000000034 method Methods 0.000 title claims abstract description 37
- 239000007788 liquid Substances 0.000 title claims abstract description 25
- 238000013461 design Methods 0.000 title claims abstract description 10
- 230000007797 corrosion Effects 0.000 claims abstract description 80
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 80
- 238000003860 storage Methods 0.000 claims abstract description 53
- 229910000975 Carbon steel Inorganic materials 0.000 claims abstract description 42
- 239000010962 carbon steel Substances 0.000 claims abstract description 42
- 238000011156 evaluation Methods 0.000 claims abstract description 22
- 239000012530 fluid Substances 0.000 claims abstract description 19
- 230000001105 regulatory effect Effects 0.000 claims abstract description 8
- 230000035876 healing Effects 0.000 claims abstract description 6
- 230000001276 controlling effect Effects 0.000 claims abstract description 5
- 238000012360 testing method Methods 0.000 claims description 14
- 238000001035 drying Methods 0.000 claims description 13
- 238000004088 simulation Methods 0.000 claims description 13
- 238000009736 wetting Methods 0.000 claims description 11
- 230000008595 infiltration Effects 0.000 claims description 9
- 238000001764 infiltration Methods 0.000 claims description 9
- 239000000463 material Substances 0.000 claims description 7
- 230000010287 polarization Effects 0.000 claims description 6
- 238000000576 coating method Methods 0.000 claims description 5
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 claims description 4
- 239000002253 acid Substances 0.000 claims description 4
- 239000011248 coating agent Substances 0.000 claims description 4
- 238000002360 preparation method Methods 0.000 claims description 4
- 238000002791 soaking Methods 0.000 claims description 4
- 230000003111 delayed effect Effects 0.000 claims description 3
- 238000005406 washing Methods 0.000 claims 1
- 239000003921 oil Substances 0.000 abstract description 112
- 230000005764 inhibitory process Effects 0.000 abstract description 7
- 230000000694 effects Effects 0.000 abstract description 6
- 239000010779 crude oil Substances 0.000 abstract description 5
- 229910001209 Low-carbon steel Inorganic materials 0.000 abstract description 4
- 239000006185 dispersion Substances 0.000 abstract description 4
- 230000002035 prolonged effect Effects 0.000 abstract description 2
- 239000012071 phase Substances 0.000 description 26
- 239000007789 gas Substances 0.000 description 11
- CSCPPACGZOOCGX-UHFFFAOYSA-N Acetone Chemical compound CC(C)=O CSCPPACGZOOCGX-UHFFFAOYSA-N 0.000 description 6
- LYCAIKOWRPUZTN-UHFFFAOYSA-N Ethylene glycol Chemical compound OCCO LYCAIKOWRPUZTN-UHFFFAOYSA-N 0.000 description 6
- 229910000831 Steel Inorganic materials 0.000 description 5
- 239000010959 steel Substances 0.000 description 5
- 230000033228 biological regulation Effects 0.000 description 4
- 239000003960 organic solvent Substances 0.000 description 4
- 230000002829 reductive effect Effects 0.000 description 4
- 239000008346 aqueous phase Substances 0.000 description 3
- 230000000052 comparative effect Effects 0.000 description 3
- 238000004945 emulsification Methods 0.000 description 3
- 238000005516 engineering process Methods 0.000 description 3
- 239000011261 inert gas Substances 0.000 description 3
- 230000009286 beneficial effect Effects 0.000 description 2
- 230000001627 detrimental effect Effects 0.000 description 2
- 238000004090 dissolution Methods 0.000 description 2
- 239000003112 inhibitor Substances 0.000 description 2
- 230000007774 longterm Effects 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 239000000203 mixture Substances 0.000 description 2
- 238000012544 monitoring process Methods 0.000 description 2
- 238000005554 pickling Methods 0.000 description 2
- 238000001179 sorption measurement Methods 0.000 description 2
- 239000000126 substance Substances 0.000 description 2
- 241000237858 Gastropoda Species 0.000 description 1
- 238000010521 absorption reaction Methods 0.000 description 1
- 238000013019 agitation Methods 0.000 description 1
- 229910045601 alloy Inorganic materials 0.000 description 1
- 239000000956 alloy Substances 0.000 description 1
- 238000013459 approach Methods 0.000 description 1
- 238000004364 calculation method Methods 0.000 description 1
- 239000003638 chemical reducing agent Substances 0.000 description 1
- 238000004140 cleaning Methods 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 238000001514 detection method Methods 0.000 description 1
- 239000000839 emulsion Substances 0.000 description 1
- 238000005265 energy consumption Methods 0.000 description 1
- 230000003628 erosive effect Effects 0.000 description 1
- 230000002349 favourable effect Effects 0.000 description 1
- 239000011152 fibreglass Substances 0.000 description 1
- 238000011049 filling Methods 0.000 description 1
- 238000011010 flushing procedure Methods 0.000 description 1
- 238000010438 heat treatment Methods 0.000 description 1
- 238000011065 in-situ storage Methods 0.000 description 1
- 238000009776 industrial production Methods 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 230000000670 limiting effect Effects 0.000 description 1
- 238000012423 maintenance Methods 0.000 description 1
- 230000014759 maintenance of location Effects 0.000 description 1
- 238000007726 management method Methods 0.000 description 1
- 239000011159 matrix material Substances 0.000 description 1
- 229910052755 nonmetal Inorganic materials 0.000 description 1
- 238000005457 optimization Methods 0.000 description 1
- 230000003647 oxidation Effects 0.000 description 1
- 238000007254 oxidation reaction Methods 0.000 description 1
- 230000036961 partial effect Effects 0.000 description 1
- 229910001562 pearlite Inorganic materials 0.000 description 1
- 230000000737 periodic effect Effects 0.000 description 1
- 230000008929 regeneration Effects 0.000 description 1
- 238000011069 regeneration method Methods 0.000 description 1
- 239000010865 sewage Substances 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 239000002904 solvent Substances 0.000 description 1
- 230000002269 spontaneous effect Effects 0.000 description 1
- 239000010935 stainless steel Substances 0.000 description 1
- 229910001220 stainless steel Inorganic materials 0.000 description 1
- 230000003068 static effect Effects 0.000 description 1
- 239000004094 surface-active agent Substances 0.000 description 1
- 238000010998 test method Methods 0.000 description 1
- 229910000859 α-Fe Inorganic materials 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
- G01N17/02—Electrochemical measuring systems for weathering, corrosion or corrosion-protection measurement
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N33/00—Investigating or analysing materials by specific methods not covered by groups G01N1/00 - G01N31/00
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Health & Medical Sciences (AREA)
- Chemical & Material Sciences (AREA)
- Immunology (AREA)
- Pathology (AREA)
- Physics & Mathematics (AREA)
- General Physics & Mathematics (AREA)
- General Health & Medical Sciences (AREA)
- Analytical Chemistry (AREA)
- Biochemistry (AREA)
- Ecology (AREA)
- Environmental & Geological Engineering (AREA)
- Biodiversity & Conservation Biology (AREA)
- Environmental Sciences (AREA)
- Engineering & Computer Science (AREA)
- Food Science & Technology (AREA)
- Medicinal Chemistry (AREA)
- Testing Resistance To Weather, Investigating Materials By Mechanical Methods (AREA)
Abstract
The application discloses a design method of a long-acting liquid anti-corrosion layer of a multiphase conveying pipeline, which comprises the following steps: step one, preparing an initial corrosion product on the surface of carbon steel; step two, regulating and controlling wettability of corrosion products; step three, preparing the carbon steel oil storage surface; step four, evaluating the durability of the oil storage surface in a water flow environment; fifthly, evaluating the reliability of the oil film under the multi-period oil-water alternating action; step six, realizing the dynamic healing and long-acting protection function of the carbon steel oil storage surface in an oil-water alternating environment; if the evaluation can be performed through the fourth step and the fifth step, the sixth step is realized, otherwise, the process returns to the second step and the third step, and a new round of evaluation is performed until the evaluation sequentially passes through the fourth step and the fifth step. According to the design method disclosed by the invention, the hydrophilic and oleophobic characteristics of corrosion products on the surface of the low-carbon steel are changed, the oil film adhesion capacity is increased, the oil film protection time is prolonged, and the corrosion inhibition effect of crude oil is enhanced in fluid environments such as slug flow, dispersion flow and the like of oil-water mixed transportation and fluid environments in an oil-water alternate transportation mode.
Description
Technical Field
The invention relates to the field of corrosion protection of oil and gas fields, in particular to a design method of a long-acting liquid anti-corrosion layer of a multiphase conveying pipeline.
Background
The oil gas pipeline conveying medium is generally oil gas water three-phase or multi-phase fluid, the flow pattern is complex and changeable, the inner wall of the pipeline is in an oil-water alternate wetting state at any time, and the corrosion protection is very challenging. At present, the technology applied to the corrosion protection of the oil and gas pipeline mainly comprises the following types of corrosion-resistant pipeline materials, lining layers or coatings, corrosion inhibitor addition and the like. The corrosion-resistant pipeline material mainly faces the problems of over high engineering cost and the like in actual industrial production, for example, the manufacturing cost of corrosion-resistant alloys such as stainless steel is several times or more than ten times that of common carbon steel pipelines; the non-metal pipelines such as glass fiber reinforced plastic and the like are only suitable for sewage or water injection pipelines, and have poor reliability in environments with large oil content and pressure fluctuation. The lining layer or coating technology mainly faces the technological problems of poor bonding strength, joint repairing and the like, and the application range is limited. The continuous addition of the corrosion inhibitor mainly has the problems of high long-term operation cost, poor corrosion inhibition effect in the multiphase flow containing oil, and the like, and is difficult to apply to the aspect of oil gas gathering and transportation pipeline protection on a large scale.
The corrosion inhibition performance of crude oil is fully utilized by flow pattern regulation and control, and is a novel pipeline corrosion protection technology which is gradually paid attention to and developed in recent years. Flow management strategies such as forced emulsification of oil and water, high gas-to-liquid ratio agitation, and high flow rate delivery have been developed for protection against corrosion of oil-water two-phase or oil-gas-water three-phase streams. The corrosion protection concept of the method is that oil-water flow is formed through oil-water dispersion, so that the direct contact frequency between the bottom of the pipeline and the water phase is reduced, and the corrosion risk is reduced. However, the forced emulsification method is generally only suitable for the situation that the comprehensive water content is lower than 30%, and the emulsion with too high water content has too high viscosity, which results in too high energy consumption for pipeline transportation; the high gas-liquid ratio corrosion inhibition method is only suitable for CO 2 The special working condition of more gas content such as oil driving; the critical flow rates required for high flow rate delivery to form the oil-water dispersed stream typically far exceed the actual production conditions. These practical problems have severely limited the effective performance of crude oil corrosion inhibition.
Therefore, a new design method for the long-acting liquid anti-corrosion layer of the multiphase conveying pipeline needs to be developed.
Disclosure of Invention
In view of the problems in the background art, an object of the present disclosure is to provide a method for designing a long-acting liquid anticorrosive layer of a multiphase conveying pipeline.
In order to achieve the above object, the present disclosure provides a method for designing a long-acting liquid anticorrosive layer of a multiphase conveying pipeline, comprising the steps of: step one, preparing an initial corrosion product on the surface of carbon steel; step two, regulating and controlling wettability of corrosion products; step three, preparing the carbon steel oil storage surface; step four, evaluating the durability of the oil storage surface in a water flow environment; fifthly, evaluating the reliability of the oil film under the multi-period oil-water alternating action; step six, realizing the dynamic healing and long-acting protection function of the carbon steel oil storage surface in an oil-water alternating environment; if the evaluation can be performed through the fourth step and the fifth step, the sixth step is realized, otherwise, the process returns to the second step and the third step, and a new round of evaluation is performed until the evaluation sequentially passes through the fourth step and the fifth step.
In some embodiments, in step one, the initial corrosion product is prepared on the surface of the pipe material using one or more of soaking, pickling, anodic polarization, and air exposure, using the oilfield produced fluid or acid fluid as the corrosion medium.
In some embodiments, in step two, the method of regulating corrosion product wettability comprises: gas drying and organic solvent drying.
In some embodiments, the gas drying method is selected from one of through-drying hot air, through-passing an inert gas.
In some embodiments, the organic solvent is selected from one of absolute ethanol, ethylene glycol, acetone.
In some embodiments, in step three, the carbon steel oil storage surface preparation method is oil phase temperature rise and delayed infiltration.
In some embodiments, in step four, the conditions for the evaluation of the durability of the oil storage surface in the aqueous flow environment are: oil film duration > water slug flow time.
In some embodiments, in the fifth step, the condition for evaluating reliability of the oil film under the action of the multi-cycle oil-water alternation is: the multicycle maximum current is less than the current threshold.
In some embodiments, the apparatus used in step four and in step five is an oil-water alternating wet corrosion simulation device.
In some embodiments, in step five, the oil-water alternating wet corrosion simulation device is a specially-made rotating cylindrical electrode.
The beneficial effects of the present disclosure are as follows:
(1) The design method of the long-acting liquid anti-corrosion layer of the multiphase conveying pipeline changes the hydrophilic and oleophobic characteristics of corrosion products on the surface of low-carbon steel, increases the adhesion capacity of an oil film, prolongs the protection time of the oil film, and can effectively enhance the corrosion inhibition effect of crude oil in fluid environments such as slug flow, dispersion flow and the like of oil-water mixed conveying and fluid environments in an oil-water alternate conveying mode. The oil film uniform adhesion time is prolonged, so that conditions such as critical flow rate for forming an oil-water dispersion flow are reduced, and the feasibility of the schemes such as traditional forced emulsification, fluid disturbance enhancement and the like is improved; meanwhile, a wider regulation window is provided for the length of the oil-water slug in the oil-water alternate conveying mode, and engineering implementation is facilitated.
(2) The corrosion product prepared by the method has a loose porous structure, is favorable for oil phase storage, and improves the difficulty of large-area replacement of the oil phase by the water phase under capillary action; the oil film is mainly damaged locally, micro liquid drops which are embedded into the oil film and are contacted with the surface of the material are separated along with the flow of the surface oil film, and the adsorption, expansion and pinning of the micro liquid drops on the oil storage surface can be avoided through the optimization of the flow speed and the oil-water interface performance, so that the oil storage surface in a flowing medium is ensured to have better corrosion resistance.
Drawings
FIG. 1 is a graph of the durability evaluation test of example 1 and comparative example 1 in different fluid environments (0 rpm, 400rpm and 800 rpm)
FIG. 2 is a graph showing the evaluation of the reliability of the multicycle oil film of example 1 and comparative example 1
Detailed Description
The method of designing the long-acting liquid anticorrosive layer of the multiphase conveying pipeline according to the present disclosure is described in detail below.
The application discloses a design method of a long-acting liquid anti-corrosion layer of a multiphase conveying pipeline, which is characterized by comprising the following steps: step one, preparing an initial corrosion product on the surface of carbon steel; step two, regulating and controlling wettability of corrosion products; step three, preparing the carbon steel oil storage surface; step four, evaluating the durability of the oil storage surface in a water flow environment; fifthly, evaluating the reliability of the oil film under the multi-period oil-water alternating action; step six, realizing the dynamic healing and long-acting protection function of the carbon steel oil storage surface in the oil-water alternating environment; if the evaluation can be performed through the fourth step and the fifth step, the sixth step is realized, otherwise, the process returns to the second step and the third step, and a new round of evaluation is performed until the evaluation sequentially passes through the fourth step and the fifth step.
The method mainly comprises the steps of preparing a corrosion product film with a multi-stage micro-scale structure on the surface of carbon steel, and carrying out proper pretreatment to convert the corrosion product film into a multifunctional surface with oil storage capacity; under the action of oil-water alternate flow, the durability of the oil film on the oil storage surface is better than the flow time of the water slug, so that the carbon steel oil storage surface is always in an oil wetting state, the contact between the carbon steel surface and water is avoided, and the corrosion risk is reduced.
And multiphase conveying pipeline refers to an oil-water two-phase conveying pipeline or an oil-gas-water three-phase conveying pipeline in the present disclosure.
In step one, the carbon steel in the invention refers to low carbon steel commonly used in oil and gas pipelines, and the microstructure of the carbon steel is generally a mixture of ferrite matrix and a small amount of pearlite at room temperature. The form and composition of the corrosion product depend on the corrosion medium and auxiliary film forming measures, the corrosion product is loose and porous, and the surface of the corrosion product presents a multi-scale microstructure and has correlation with the original tissue structure of the low-carbon steel.
In some embodiments, in step one, the initial corrosion product is prepared on the surface of the pipe material using one or more of soaking, pickling, anodic polarization, and air exposure, using the oilfield produced fluid or acid fluid as the corrosion medium.
In some embodiments, in step two, the method of regulating corrosion product wettability comprises: gas drying and organic solvent drying. The prepared or cleaned corrosion product needs to be dried, the absorbed moisture in the corrosion product is removed, the influence of the moisture absorption effect of the corrosion product on the wettability of the corrosion product is weakened, and simultaneously, all stages of microstructures are fully exposed and mutually communicated, so that preparation is carried out for oil phase infiltration.
Corrosion products formed in the aqueous phase have hydrophilic hygroscopic properties, which are detrimental to oil film surface adsorption. Residual moisture can be effectively removed through drying, and the oil storage functional surface with good performance can be quickly and completely formed in the oil phase infiltration stage. Due to the three-dimensional defect incompleteness of the corrosion product on the surface of the carbon steel, spontaneous infiltration and expansion of the oil phase occur on the surface of the dried corrosion product. For example, the expansion speed of No. 10 industrial white oil can reach 5.0mm/min.
In some embodiments, the gas drying method is selected from one of through-drying hot air, through-passing an inert gas. The moisture in the corrosion product is carried away by drying the hot air or inert gas.
In some embodiments, the organic solvent is selected from one of absolute ethanol, ethylene glycol, acetone. The water in the corrosion product is absorbed by the solvent, and then air-dried or naturally dried.
In some embodiments, in step three, the carbon steel oil storage surface preparation method is oil phase temperature rise and delayed infiltration. The corrosion product after drying treatment is immersed in the oil phase, the oil storage surface with better infiltration can be obtained by prolonging the time and increasing the temperature of the oil phase, and the micro negative pressure method is adopted to help shorten the time required for complete infiltration under the premise of allowable process and economy.
In some embodiments, the oil phase may be a different model of industrial white oil, dehydrated crude oil, or other simulated oil. The infiltration time and the retention temperature of the high-performance oil storage surface obtained in different oil phases are required to be comprehensively evaluated and determined through a viscosity-temperature curve and an operating environment.
In some embodiments, in step four, the conditions for the evaluation of the durability of the oil storage surface in the aqueous flow environment are: oil film duration > water slug flow time. The obtained carbon steel oil storage surface needs to be kept for enough time to avoid damage under the condition of water flow flushing, and the duration time of the carbon steel oil storage surface is longer than the water phase action time under the oil-water alternating environment; if the criterion cannot be met, returning to the second step and the third step; meanwhile, when the oil slugs pass, the oil film on the carbon steel oil storage surface can be updated and locally repaired.
In some embodiments, in the fifth step, the condition for evaluating reliability of the oil film under the action of the multi-cycle oil-water alternation is: the multicycle maximum current is less than the current threshold. The current threshold is defined as the corrosion rate (expressed and monitored in terms of current) of the carbon steel material in an oil-free film protection in an aqueous environment, such as 1%: the meaning is that the oil film integrity degree is 99% in the test range, or the corrosion inhibition efficiency is maintained at 99%.
In the fifth and sixth steps, the oil-water alternate environment comprises a service environment adopting an oil-water slug alternate conveying mode, and a service environment in which oil-water in complex flowing states such as slug flow, dispersed flow and the like in an oil-water mixed conveying mode alternately acts on the inner wall of the pipeline.
In some embodiments, the apparatus used in step four and in step five is an oil-water alternating wet corrosion simulation device.
The oil-water alternate wetting corrosion simulation device is equipment in a publication number of CN 105092460B.
In some embodiments, in step five, the oil-water alternating wet corrosion simulation apparatus employs a specially-made rotating cylindrical electrode. The effective test height is not more than 10mm, and the effective diameter is 10-20mm.
In the method, an oil-water alternate wetting corrosion simulation device is adopted to determine critical fluid conditions of local damage of the oil storage surface under the action of water flow, namely fluid Reynolds numbers (or flow rates), alternate frequencies, wetting duration, temperatures and the like corresponding to current critical limit values are reached. The simulation of the near-wall fluid state and water-to-oil process is realized by adopting a rotary cylindrical electrode system. Reynolds number R of rotating cylindrical electrode e The calculation basis is as follows:
where ω is the angular velocity of the rotating cylindrical electrode, d is the effective diameter of the rotating cylindrical electrode, and v is the dynamic viscosity of the aqueous phase.
And optimizing and determining the critical fluid condition of the oil film stability of the oil storage surface according to the simulation test. When the fluid is converted into a turbulent state from laminar flow, micro liquid drops which cause local damage of an oil film are difficult to stably adsorb on the oil storage surface, and the oil storage surface can present certain self-healing capacity, so that a corresponding Re value at the moment is obtained and is used as an engineering design basis.
The micro liquid drops are adsorbed on the carbon steel oil storage surface, the corrosion process is self-limiting expansion, and when the liquid drops are pinned on the surface, corrosion products can fill the whole liquid drops and form a new oil storage structure, so that the durability of the oil storage structure is further enhanced.
To facilitate the detachment of the microdroplet from the oil storage surface, in the engineering implementation of step six, physical and chemical methods may be employed including: (1) proper regulation of flow rate; (2) The temperature of the fluid is regulated and controlled by short-time heating or adding a viscosity reducer into a pipeline; (3) Intermittently filling high-dose surfactant into an oil slug or a water slug in a pipeline; (4) periodic cleaning, etc.
After the multi-period oil-water alternating action, if the current indicating the oil film rupture reaches a current critical value, adopting a preferable physical and chemical method to recover the local oil film breakage; when the maximum current continues to exceed the current threshold value for a plurality of periods, the second and third steps need to be executed back. The long-acting corrosion protection of the carbon steel surface under the alternating action of oil and water can be realized by the reciprocating.
And (3) monitoring the response relation of the current in at least 50 oil-water alternating periods along with time in real time by adopting an oil-water alternating wetting corrosion simulation device, and judging the restorability of the oil film under the action of multiple periods according to the variation trend of the maximum value of the current in each period.
In the sixth step, the local damage and liquid drop pinning of the oil film on the carbon steel oil storage surface can be dynamically recovered in the oil-water alternation process, and the main appearance is that: the micro-droplets slide and separate from the surface under the action of the flow; the micro-droplets are pinned and eroded for a long time, so that erosion products are filled in the droplet space, and a new oil storage microstructure is formed. Meanwhile, after the multi-period oil-water alternating action, the damage and failure of the oil storage surface are serious, and the regeneration is needed. The multi-period corrosion signal monitoring system is beneficial to early identification of local damage of an oil film, and utilizes corrosion signals such as critical current and the like to determine the best time for preparing the oil storage surface in situ for a new round, so that the operation reliability and the economic feasibility are improved.
[ test procedure and test results ]
Example 1
Step one, preparing an initial corrosion product on the surface of carbon steel:
selecting common No. 20 steel, adopting a mode of combining triple constant potential polarization and air exposure, firstly adding 0.1mol/L NaCI+0.01mol/L NaHCO 3 Developing a constant potential polarization test of +0.4V (relative to open circuit potential) for 3600s in the solution to form a morphology of carbon steel surface two-phase uneven dissolution, and then exposing the carbon steel surface two-phase uneven dissolution in air for 10 hours to form partial oxide on a surface initial corrosion structure; repeating the potentiostatic polarization and air exposure processes for 3 times to obtain a multi-stage non-uniform surface corrosion product spanning from micron to nanometer scale in a two-phase galvanic corrosion, pitting corrosion and fine oxidation structure;
step two, regulating and controlling wettability of corrosion products:
immersing the formed multi-stage structure corrosion product in absolute ethyl alcohol to remove the moisture in the microstructure, and then drying by flowing air;
step three, preparing a carbon steel oil storage surface:
soaking the dried carbon steel corrosion product in No. 10 industrial white oil at the temperature of more than 40 ℃ for 1 hour, taking out, standing vertically, and obtaining the carbon steel oil storage surface after excessive oil drops drop down;
step four, evaluating the durability of the oil storage surface in a water flow environment:
the effective test height of the rotary cylindrical electrode is 5mm, and the effective diameter is 10mm; on the premise of ensuring stable test current and avoiding edge effect, reducing the influence of oil-water alternation time lag as much as possible, and under the conditions that the fluid environment is static (0 rpm), 400rpm and 800rpm, carrying out durability evaluation on the carbon steel oil storage surface;
fifthly, oil film reliability evaluation under multi-period oil-water alternation effect:
in order to evaluate the long-term protection reliability of the oil storage surface, the oil phase stays for 1min, the water phase stays for 10min, and a circulation test of 50 periods is carried out in an oil-water alternate wetting simulation device;
step six, realizing the dynamic healing and long-acting protection function of the carbon steel oil storage surface in an oil-water alternating environment;
if the evaluation can be performed through the fourth step and the fifth step, the sixth step is realized, otherwise, the process returns to the second step and the third step, and a new round of evaluation is performed until the evaluation sequentially passes through the fourth step and the fifth step.
The test results are shown in fig. 1 and 2.
Comparative example 1
The common No. 20 steel is not corroded and subjected to wetting regulation; the untreated surface was hereinafter referred to and subjected to the evaluation test in the same manner as in step four and step five of example 1.
The test results are shown in fig. 1 and 2.
As shown in fig. 1, the durability of the carbon steel oil storage surface was significantly better than the untreated surface at rest (0 rpm), 400rpm and 800 rpm. The limiting current value of oil film rupture is 50 mu A, which is only about 1% of the current value of bare steel.
At 400rpm, the oil film durability was optimized, which was 6000s to 10000s in duration in water flow. At this point, the Reynolds number of the aqueous phase was 2093, at the turbulent/laminar boundary.
When the reynolds number reaches 4187 (800 rpm), the oil film durability time shortens to the 600-4000s range (fig. 1 c), and it is apparent that too high reynolds number is detrimental to the maintenance of the oil film integrity.
The result shows that the carbon steel oil storage surface can keep good stability for thousands of seconds under the condition of water phase turbulent flow conveying, and meets the engineering transportation requirement.
As shown in fig. 2, after 50 cycles of circulation at 400rpm, the carbon steel oil storage surface still maintains a very low detection current value which is only about 1/10000 of the current value of bare steel, and the carbon steel oil storage surface shows extremely high protection capability and healing capability under the alternating action of oil and water; for untreated surfaces, only a few cycles are needed, and the current value reaches or approaches the current value of bare steel, so that the oil film protection capability of the surface is completely lost.
The above disclosed features are not intended to limit the scope of the disclosure, and therefore, equivalent variations to what is described in the claims of the disclosure are intended to be included within the scope of the claims of the disclosure.
Claims (4)
1. The design method of the long-acting liquid anti-corrosion layer of the multiphase conveying pipeline is characterized by comprising the following steps:
step one, preparing an initial corrosion product on the surface of carbon steel;
regulating and controlling wettability of corrosion products, immersing the formed multi-stage structure corrosion products in absolute ethyl alcohol to remove moisture in the microstructures, and drying by flowing air, so that the microstructures of each stage are fully exposed and mutually communicated, and preparing for oil phase infiltration in advance;
step three, preparing the carbon steel oil storage surface;
step four, evaluating the durability of the oil storage surface in a water flow environment, wherein the effective test height of the rotary cylindrical electrode is 5mm, and the effective diameter is 10mm; performing durability assessment of the carbon steel oil storage surface under the conditions that the fluid environment is 0rpm, 400rpm and 800 rpm;
fifthly, evaluating the reliability of an oil film under the multi-period oil-water alternating action, staying in an oil phase for 1min, staying in a water phase for 10min, and carrying out a 50-period circulation test in an oil-water alternating wetting simulation device;
step six, realizing the dynamic healing and long-acting protection function of the carbon steel oil storage surface in an oil-water alternating environment;
if the evaluation can be performed through the fourth step and the fifth step, the sixth step is realized, otherwise, the process returns to the second step and the third step, and a new round of evaluation is performed until the evaluation sequentially passes through the fourth step and the fifth step;
in the third step, the preparation method of the carbon steel oil storage surface is that the temperature of the oil phase rises and the oil phase is soaked in a delayed manner;
in the fourth step, the conditions for evaluating the durability of the oil storage surface in the water flow environment are as follows: oil film duration > water slug flow time;
in the fifth step, the condition for evaluating the reliability of the oil film under the multi-period oil-water alternation action is as follows: the multicycle maximum current is less than the current threshold.
2. The method for designing a long-acting liquid anticorrosive coating for a multiphase conveying pipeline according to claim 1, wherein,
in the first step, oil field produced liquid or acid liquid is used as a corrosion medium, and one or more processes of soaking, acid washing, anodic polarization and air exposure are adopted to prepare an initial corrosion product on the surface of the pipeline material.
3. The method for designing a long-acting liquid anticorrosive coating for a multiphase conveying pipeline according to claim 1, wherein,
the equipment used in the fourth step and the fifth step is an oil-water alternate wetting corrosion simulation device.
4. The method for designing a long-acting liquid anticorrosive coating for a multiphase conveying pipeline according to claim 1, wherein,
in the fifth step, the oil-water alternate wetting corrosion simulation device adopts a special rotary cylindrical electrode.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202111351409.4A CN114062243B (en) | 2021-11-15 | 2021-11-15 | Design method of long-acting liquid anti-corrosion layer of multiphase conveying pipeline |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202111351409.4A CN114062243B (en) | 2021-11-15 | 2021-11-15 | Design method of long-acting liquid anti-corrosion layer of multiphase conveying pipeline |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN114062243A CN114062243A (en) | 2022-02-18 |
| CN114062243B true CN114062243B (en) | 2024-04-05 |
Family
ID=80272751
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202111351409.4A Active CN114062243B (en) | 2021-11-15 | 2021-11-15 | Design method of long-acting liquid anti-corrosion layer of multiphase conveying pipeline |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN114062243B (en) |
Citations (8)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| JPS558417A (en) * | 1978-06-30 | 1980-01-22 | Nippon Steel Corp | Production of high corrosion resistant coated steel material |
| WO2001057428A2 (en) * | 2000-02-01 | 2001-08-09 | Beb Erdgas & Erdoel Gmbh | Method for protecting conduits used for transporting natural gas against internal corrosion |
| CN102051612A (en) * | 2010-12-02 | 2011-05-11 | 西北工业大学 | Method for preparing super-hydrophobic lubricant coating on surface of light metal |
| CN105092460A (en) * | 2015-06-23 | 2015-11-25 | 中石化石油工程设计有限公司 | Oil-water alternating wetting corrosion simulation device and method |
| CN109520919A (en) * | 2018-10-31 | 2019-03-26 | 中国海洋石油集团有限公司 | A kind of corrosion simulated device and method of on-line checking multiphase flow pipeline oil-water interfaces |
| CN109856036A (en) * | 2018-12-27 | 2019-06-07 | 中国石油工程建设有限公司 | A kind of high temperature and pressure gas, liquid, solid three-phase erosion corrosion test device and method |
| CN110359044A (en) * | 2019-08-14 | 2019-10-22 | 重庆大学 | A kind of preparation method of steel matrix surface ultra-hydrophobic water film |
| US10907258B1 (en) * | 2016-08-25 | 2021-02-02 | Arrowhead Center, Inc. | Surface modification of metals and alloys to alter wetting properties |
Family Cites Families (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101576471B (en) * | 2009-04-27 | 2011-11-30 | 中国石油大学(北京) | Test device for realizing multiphase pipe flow and washing erosion in high-temperature high-pressure reaction kettle |
| WO2015103107A1 (en) * | 2013-12-30 | 2015-07-09 | Solidia Technologies, Inc. | Anticorrosive coatings, processes and uses thereof |
| GB2538899B (en) * | 2014-09-03 | 2017-04-12 | Schlumberger Holdings | A Method of Corrosion inhibition of Duplex Steel |
| EP3601722B1 (en) * | 2017-03-24 | 2023-03-01 | Saudi Arabian Oil Company | Mitigating corrosion of carbon steel tubing and surface scaling deposition in oilfield applications |
| US20190025189A1 (en) * | 2017-07-21 | 2019-01-24 | Saudi Arabian Oil Company | Corrosion testing system for multiphase environments using electrochemical and weight-loss methods |
-
2021
- 2021-11-15 CN CN202111351409.4A patent/CN114062243B/en active Active
Patent Citations (8)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| JPS558417A (en) * | 1978-06-30 | 1980-01-22 | Nippon Steel Corp | Production of high corrosion resistant coated steel material |
| WO2001057428A2 (en) * | 2000-02-01 | 2001-08-09 | Beb Erdgas & Erdoel Gmbh | Method for protecting conduits used for transporting natural gas against internal corrosion |
| CN102051612A (en) * | 2010-12-02 | 2011-05-11 | 西北工业大学 | Method for preparing super-hydrophobic lubricant coating on surface of light metal |
| CN105092460A (en) * | 2015-06-23 | 2015-11-25 | 中石化石油工程设计有限公司 | Oil-water alternating wetting corrosion simulation device and method |
| US10907258B1 (en) * | 2016-08-25 | 2021-02-02 | Arrowhead Center, Inc. | Surface modification of metals and alloys to alter wetting properties |
| CN109520919A (en) * | 2018-10-31 | 2019-03-26 | 中国海洋石油集团有限公司 | A kind of corrosion simulated device and method of on-line checking multiphase flow pipeline oil-water interfaces |
| CN109856036A (en) * | 2018-12-27 | 2019-06-07 | 中国石油工程建设有限公司 | A kind of high temperature and pressure gas, liquid, solid three-phase erosion corrosion test device and method |
| CN110359044A (en) * | 2019-08-14 | 2019-10-22 | 重庆大学 | A kind of preparation method of steel matrix surface ultra-hydrophobic water film |
Non-Patent Citations (6)
| Title |
|---|
| Elecfrochemical Characterization of an Oil/Water Alternately Wetted Rotating Cylinder Electrode;linxiao Zheng et al;CORROSION;20210131;第77卷(第1期);第72-84页 * |
| Wang, Kai et al.Batch Transportation of Oil and Water for Reducing Pipeline Corrosion.JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING.2021,第195卷全文. * |
| Wang, Zi Ming et al.Corrosion mitigation behavior of an alternately wetted steel electrode in oil/water media.CORROSION SCIENCE.2019,第152卷第141页左栏第15行-右栏最后一行、第151页左栏第15-35行. * |
| Wang, Zi Ming et al.Fluid structure governing the corrosion behavior of mild steel in oil-water mixtures.CORROSION ENGINEERING SCIENCE AND TECHNOLOGY.2020,第55卷(第3期),第241-252页. * |
| 张星 等.高温高压CO2驱采出液中N80碳钢局部腐蚀诱发机理.腐蚀与防护.2021,第42卷(第4期),第36-42页. * |
| 王子明 等.基于润湿调控的管道多相流腐蚀防护技术.第十一届全国腐蚀与防护大会论文摘要集.2021,第1-2页. * |
Also Published As
| Publication number | Publication date |
|---|---|
| CN114062243A (en) | 2022-02-18 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| Zhang et al. | A review of the recent advances in superhydrophobic surfaces and the emerging energy-related applications | |
| Vazirian et al. | Surface inorganic scale formation in oil and gas industry: As adhesion and deposition processes | |
| Xie et al. | Contact angle hysteresis and the stability of wetting changes induced by adsorption from crude oil | |
| Ahn et al. | Anti-fouling performance of chevron plate heat exchanger by the surface modification | |
| US6523615B2 (en) | Electropolishing method for oil field tubular goods and drill pipe | |
| Neville et al. | A combined bulk chemistry/electrochemical approach to study the precipitation, deposition and inhibition of CaCO3 | |
| Mora-Mendoza et al. | Influence of turbulent flow on the localized corrosion process of mild steel with inhibited aqueous carbon dioxide systems | |
| Song et al. | Antifouling and anticorrosion behaviors of modified heat transfer surfaces with coatings in simulated hot-dry-rock geothermal water | |
| CN114062243B (en) | Design method of long-acting liquid anti-corrosion layer of multiphase conveying pipeline | |
| JP2015120153A (en) | Abrasive cleaning of internally cooled generator coil | |
| Li et al. | Designing an oil-impregnated surface on carbon steel with superior corrosion resistance to oil-water alternating flows | |
| Rao et al. | Erosion‐Corrosion of Materials in Industrial Equipment: A Review | |
| Quale et al. | Cathodic protection by distributed sacrificial anodes–A new cost-effective solution to prevent corrosion of subsea structures | |
| Weng et al. | De-icing performance evolution with increasing hydrophobicity by regulating surface topography | |
| Wang et al. | Exploring the dynamic mechanism of water wetting induced corrosion on differently pre-wetted surfaces in oil–water flows | |
| Kvarekval et al. | Pitting corrosion in CO2/H2S containing glycol solutions under flowing conditions | |
| Jung et al. | A simulation study of wax deposition in subsea oil production system | |
| Zhang et al. | Anti-corrosion study of tungsten alloy coating on tube column under high CO2 partial pressure | |
| Achour et al. | A novel laboratory test method to determine film persistency of batch inhibitors used to mitigate top of the line corrosion | |
| Raheem et al. | Surface Precipitation and Growth Kinetics of Calcium Carbonate (CaCO3) Scale Using a Novel Capillary Flow Rig | |
| Calderón et al. | The corrosion process of P-110 steel in stimulation fluids used in the oil industry | |
| US20210063056A1 (en) | Introduction of co2 into thermal water | |
| Doležal et al. | Inhibition of carbon steel corrosion by imidazoline in carbon dioxide saturated oilfield brine solution | |
| RU2740462C1 (en) | Method of preventing formation of asphaltene, resinous paraffin deposits (arpd) in lift pipes during gas-lift operation of oil wells | |
| Knudsen et al. | Internal Coating Of Multiphase Pipelines-Requirements For The Coating |
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 | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant |