CN104251812A - High-acidity gas field wellbore string material optimization evaluation system and method - Google Patents
High-acidity gas field wellbore string material optimization evaluation system and method Download PDFInfo
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- 239000000463 material Substances 0.000 title claims abstract description 86
- 238000011156 evaluation Methods 0.000 title claims abstract description 61
- 238000000034 method Methods 0.000 title claims abstract description 43
- 238000005457 optimization Methods 0.000 title abstract description 10
- 238000005260 corrosion Methods 0.000 claims abstract description 130
- 230000007797 corrosion Effects 0.000 claims abstract description 125
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 claims abstract description 39
- 238000004088 simulation Methods 0.000 claims abstract description 21
- 229910052717 sulfur Inorganic materials 0.000 claims abstract description 18
- 239000011593 sulfur Substances 0.000 claims abstract description 18
- 239000000126 substance Substances 0.000 claims abstract description 6
- 239000007789 gas Substances 0.000 claims description 63
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 claims description 58
- 238000012360 testing method Methods 0.000 claims description 26
- 239000000956 alloy Substances 0.000 claims description 25
- 229910045601 alloy Inorganic materials 0.000 claims description 23
- 239000005864 Sulphur Substances 0.000 claims description 18
- 230000008021 deposition Effects 0.000 claims description 16
- 230000007613 environmental effect Effects 0.000 claims description 16
- 238000006243 chemical reaction Methods 0.000 claims description 14
- 230000008569 process Effects 0.000 claims description 13
- 238000011160 research Methods 0.000 claims description 13
- 229910000975 Carbon steel Inorganic materials 0.000 claims description 11
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 claims description 11
- 239000010962 carbon steel Substances 0.000 claims description 11
- 230000008859 change Effects 0.000 claims description 11
- 229910052739 hydrogen Inorganic materials 0.000 claims description 11
- 239000001257 hydrogen Substances 0.000 claims description 11
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 10
- 125000004122 cyclic group Chemical class 0.000 claims description 4
- 238000007789 sealing Methods 0.000 claims description 3
- 238000004519 manufacturing process Methods 0.000 abstract description 13
- 238000011161 development Methods 0.000 abstract description 7
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- 238000002474 experimental method Methods 0.000 description 14
- 238000004458 analytical method Methods 0.000 description 12
- 239000002253 acid Substances 0.000 description 8
- 229910000037 hydrogen sulfide Inorganic materials 0.000 description 7
- 238000007726 management method Methods 0.000 description 7
- 238000005516 engineering process Methods 0.000 description 6
- 239000012530 fluid Substances 0.000 description 6
- 239000000203 mixture Substances 0.000 description 6
- 238000012544 monitoring process Methods 0.000 description 6
- 230000018109 developmental process Effects 0.000 description 5
- 238000011084 recovery Methods 0.000 description 5
- 230000008901 benefit Effects 0.000 description 3
- 230000015572 biosynthetic process Effects 0.000 description 3
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- 230000006378 damage Effects 0.000 description 3
- 238000013461 design Methods 0.000 description 3
- 230000000694 effects Effects 0.000 description 3
- XEEYBQQBJWHFJM-UHFFFAOYSA-N Iron Chemical compound [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 description 2
- PXHVJJICTQNCMI-UHFFFAOYSA-N Nickel Chemical compound [Ni] PXHVJJICTQNCMI-UHFFFAOYSA-N 0.000 description 2
- 230000002378 acidificating effect Effects 0.000 description 2
- 239000003153 chemical reaction reagent Substances 0.000 description 2
- 239000008367 deionised water Substances 0.000 description 2
- 229910021641 deionized water Inorganic materials 0.000 description 2
- 238000004090 dissolution Methods 0.000 description 2
- 230000003628 erosive effect Effects 0.000 description 2
- 238000013210 evaluation model Methods 0.000 description 2
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- 239000007788 liquid Substances 0.000 description 2
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- 229920006395 saturated elastomer Polymers 0.000 description 2
- 238000010998 test method Methods 0.000 description 2
- 238000012795 verification Methods 0.000 description 2
- 229910000851 Alloy steel Inorganic materials 0.000 description 1
- 235000007926 Craterellus fallax Nutrition 0.000 description 1
- 240000007175 Datura inoxia Species 0.000 description 1
- YGYAWVDWMABLBF-UHFFFAOYSA-N Phosgene Chemical compound ClC(Cl)=O YGYAWVDWMABLBF-UHFFFAOYSA-N 0.000 description 1
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Abstract
The invention provides a high-acidity gas field wellbore string material optimization evaluation system and method, and belongs to the field of high-acidity gas field development. The high-acidity gas field wellbore string material optimization evaluation system includes a corrosion rate prediction model and a stress corrosion cracking boundary model; the corrosion rate prediction model includes H2S partial pressure-temperature, H2S partial pressure-CO2 partial pressure and elementary substance S-pH value corrosion rate prediction drawing boards; the stress corrosion cracking boundary model includes a failure boundary of a material under conditions of the temperature and the H2S partial pressure and a failure boundary of the material after sulfur is separated out under the conditions of the temperature and the H2S partial pressure. The system and the method solve the problems that due to a corrosion simulation evaluation method and a corrosion prediction model and software, a gas field highly containing H2S/CO2 is lack of basis on material selection, and provide a theoretical support for high-acidity gas field development and safety production.
Description
Technical field
The invention belongs to high sour gas well development field, be specifically related to a kind of high sour gas well shaft column material optimizing evaluation system and method.
Background technology
Marine Basin is the main region of China's oil-gas exploration and development always, particularly in recent years, along with basin Songliao basin improve, geological knowledge deepens continuously, the continuous progress of exploration engineering, found the gas reservoir such as general light, first dam, bight, Luo Jiazhai, Tie Shan, Dukouhe, iron hillside successively at Northeast Sichuan area.These gas reservoir Effective Reservoirs thickness are large, per-well production is high, hydrogen sulfide content is high, reserves scale is large.
Due to marine gas hide bury dark and high containing H
2s and CO
2feature, its performance history will face many international technology difficult problems.In recovery process, fluid is along in pit shaft uphill process, along with the reduction of temperature, pressure, can whether the component in gas can change, particularly form sulphur deposition, whether to produce under hydrate, different output the change in pressure drop rule of fluid in pit shaft etc. is not also grasped, the selection of wellbore materials is lacked and understands systematicly, gas field Material selec-tion higher than 1MPa is lacked and instructs, to height containing H
2s and CO
2under environment, the corrosion resisting property of material and all ununified understanding of corrosion resistance mechanism bring very big technical barrier to gas-field exploitation and conveying.
High sour gas well shaft column optimization method of the present invention is researched and developed for high sour gas well gas producing technology stage wellbore materials corrosion evaluation and prediction.At present for high sour gas well shaft column in acid gas field pit shaft optimizing evaluation process, the physical parameter of high sour gas well pit shaft real fluid need be obtained.Acid gas field H
2s content is high, and gas reservoir pressure is large.In recovery process, maximum feature possible have elemental sulfur to separate out in the wellbore, causes general phosgene field gas flow condition in the wellbore very complicated, the research of deep-well rock gas polyphasic flow flow model, also do not relate to high containing H at present
2s/CO
2singularity problem, polyphasic flow theory can not adapt to this operating mode in the past.
In existing technology, international standard ISO15156 does not also instruct the gas field Material selec-tion higher than 1MPa, to height containing H
2s and CO
2the corrosion resisting property of material and all ununified understanding of corrosion resistance mechanism under environment, about H in VII grade standard the highest in the evaluation method of nickel-base alloy
2s dividing potential drop also only has 3.5MPa, well below high sour gas well down-hole H
2s partial pressure conditions, the Simulation evaluation of high sour gas well down-hole wellbore materials lacks standard and experience instructs, and brings great challenge to high sour gas well corrosion research work.
High containing H
2s/CO
2gas field is in recovery process, and prior art exists following problem:
1. in recovery process due to H
2the existence of S, may form sulphur deposition in the wellbore, aborning once form sulphur deposition, the serious harm of blocking flow channel or wellbore materials corrosion can be brought, producing well even can be made to scrap, at present, in recovery process, cannot judge whether to form sulphur deposition in the wellbore; Be difficult to the position judging that sulphur deposits; Gas is difficult to prediction along journey change of component rule in pit shaft; High containing H
2s/CO
2gas field pit shaft Multiphase Flow rule is failed to understand.
2, corrosion evaluation method cannot at experiment lab simulation height H in the past
2s dividing potential drop (> 3.5MPa) condition, and the corrosion evaluation adopting simulated field environment to carry out tests unpredictable material military service performance, lacks sulphur deposit corrosion evaluation method.
3, start late for the corrosion research of material under high sour gas well environment both at home and abroad, not yet being formed can directly for corrosion prediction model and the software of onsite application.General corrosion evaluation model and inefficacy method of discrimination cannot the safety in utilization of material carry out analysis and judge and carry out venture analysis under the environment of overbased acidic gas field.
At present, the measure of systematic analysis high sour gas well shaft column optimal design is not yet set up both at home and abroad.
Summary of the invention
The object of the invention is to solve the difficult problem existed in above-mentioned prior art, a kind of high sour gas well shaft column material optimizing evaluation system and method is provided, for high sour gas well exploitation and safety in production provide theory support.
The present invention is achieved by the following technical solutions:
A kind of high sour gas well shaft column material optimizing evaluation system, comprises corrosion rate forecast model and stress corrosion crack boundary model;
Described corrosion rate forecast model comprises H
2s dividing potential drop-temperature, H
2s dividing potential drop-CO
2the corrosion rate prediction chart board of dividing potential drop and simple substance S-pH value;
Described stress corrosion crack boundary model comprises material at temperature and H
2after Failure Boundaries under S partial pressure conditions and Sulfur releasing, material is at temperature and H
2failure Boundaries under S partial pressure conditions.
A kind of high sour gas well shaft column material optimizing evaluation method, described method comprises:
Determine environmental baseline and parameter;
At high H
2under S partial pressure conditions, speeding-up simulation test is carried out to the material corrosion performance of nickel-base alloy tubing and casing;
At high H
2under S partial pressure conditions, speeding-up simulation test is carried out to the corrosive nature of carbon steel tubing and casing material.
Describedly determine that environmental baseline and parameter are achieved in that
Analyzing along under the condition of each change of component of pit shaft, sulphur deposition, change of flow state and thermal loss, set up high containing H
2s/CO
2gas field pit shaft Multiphase Flow law forecasting model, described forecast model comprises comprehensive pressure-drop model, thermograde model and sulphur deposition forecast model.
Described at high H
2carry out speeding-up simulation test to the material corrosion performance of carbon steel tubing and casing under S partial pressure conditions to be achieved in that
1, prepare on-the-spot gas field recovered water solution, empirically aequum adds in high-temperature high-pressure reaction kettle;
2, on the basis ensureing the temperature and pressure value identical with work condition environment, adjust the pH value of described solution, make test environment reach maximum and ooze hydrogen saturation conditions;
3, according to site environment parameter, at High Temperature High Pressure height containing H
2s/CO
2the research of corrosion coupon and stress corrosion is carried out under environment.
Described at high H
2carry out speeding-up simulation test to the corrosive nature of nickel-base alloy tubing and casing material under S partial pressure conditions to be achieved in that
1, prepare the on-the-spot recovered water solution in gas field, empirically aequum adds in high-temperature high-pressure reaction kettle;
2, on the basis of improving ambient temperature conditions, according to site environment parameter, at High Temperature High Pressure height containing H
2s/CO
2the research of corrosion coupon and stress corrosion is carried out under environment.
Described height is containing H
2s/CO
2environment is achieved in that
1, sulfuretted hydrogen gas cylinder is at room temperature utilized to pass into H in the high-temperature high-pressure reaction kettle of sealing
2s gas;
2, H is treated
2s fully dissolves, and when the indicating gauge of high-temperature high-pressure reaction kettle shows pressure drop, again passes into H
2s gas;
3, repeatedly H is carried out
2s passes into-dissolves-pass into this cyclic process again, and make it dissolve and reach determined amounts;
4, heat temperature raising, makes H
2s dividing potential drop reaches the H specified
2s partial pressure conditions;
5, with gas cylinder directly by CO
2pass into airtight high-temperature high-pressure reaction kettle, stop after reaching set pressure.
Compared with prior art, the invention has the beneficial effects as follows:
The invention solves high containing H
2s/CO
2gas field selection lacks a difficult problem for foundation, proposes corrosion simulated evaluation method and corrosion prediction model and software, for high sour gas well exploitation and safety in production provide theory support.
Meanwhile, this theory is successfully applied to general smooth gas field development on-the-spot, successfully solves the on-the-spot etching problem existed, analysis is optimized to on-the-spot material, and successfully facilitates the production domesticization of nickel-bass alloy material, economic benefits.
The present invention is applicable to the evaluation of all acid gas field material corrosions and Material selec-tion, particularly can be used successfully to the evaluation of high sour gas well material corrosion and Material selec-tion.
Accompanying drawing explanation
Fig. 1 is H under different temperatures
2the pressure of S
Fig. 2 is different H
2diffusible hydrogen content contrast under S partial pressure conditions
Fig. 3 is the erosion profile of nickel-base alloy G3 under varying environment condition
Fig. 4 is the corrosion regularity of nickel-base alloy under different temperatures
Fig. 5 is the H of nickel-base alloy G3
2s dividing potential drop-temperature corrosion rate prediction chart board
Fig. 6 is the H of nickel-base alloy G3
2s dividing potential drop-CO
2dividing potential drop corrosion rate prediction module
Fig. 7 is the simple substance S-pH value corrosion rate prediction module of nickel-base alloy G3
Fig. 8 is that nickel-base alloy G3 is based on temperature and H
2the Failure Boundaries of S dividing potential drop
Fig. 9 is nickel-base alloy G3 temperature and H when elementary sulfur exists
2the contraction Failure Boundaries of S dividing potential drop
Figure 10 corrosion evaluation software systems are formed.
Embodiment
Below in conjunction with accompanying drawing, the present invention is described in further detail:
The invention provides a whole set of high sour gas well shaft column system optimization method, comprise two parts: wellbore materials corrosion accelerated evaluation test and Corrosion Evaluation system.
(1) high sour gas well wellbore materials corrosion accelerated evaluation test
The object of the present invention is to provide a set of evaluation high sour gas well tubing and casing material corrosion evaluation test method, problem to be solved by this invention overcomes existing experimental technique cannot meet the on-the-spot High Temperature High Pressure height of simulation high sour gas well containing H
2s/CO
2the problem of environment, the analogue experiment method evaluating apparatus that the present invention adopts is simple, easy to operate, and evaluation result is examined with reality and conformed to.
The present invention is achieved through the following technical solutions:
The invention provides a kind of at laboratory simulation height H
2the analogue experiment method of S dividing potential drop, described method repeatedly carries out H at low temperatures
2s passes into-dissolves-pass into this cyclic process again, and reach and fully dissolve H in media as well
2the object of S, makes it dissolve and reaches determined amounts, and then heat temperature raising supercharging, makes H
2s dividing potential drop reaches the H specified
2s partial pressure conditions.
Wherein high sour gas well wellbore materials corrosion accelerated evaluation test is included in laboratory simulation height H
2the simulation experiment method of S dividing potential drop, carbon steel tubing and casing material corrosion performance speeding-up simulation evaluation method and nickel-base alloy tubing and casing material corrosion performance speeding-up simulation evaluation method, these three methods are to realize environmental baseline analogy method that tubing string evaluation of material takes and evaluation method, first method uses respectively together with latter two method, high sour gas well variety classes tubing string evaluation of material needs can be completed, all will at high H both rear
2s divides pressure to carry out evaluation experimental, and then both are respectively to the corrosion evaluation experiment that carbon steel and nickel-base alloy are carried out.
Wherein Corrosion Evaluation system provides a set of high sour gas well tubing and casing material evaluation and optimization model and software, mainly comprises corrosion rate prediction and stress corrosion crack predicts two kinds of models and a kind of Corrosion Evaluation software systems.
The present invention achieves good effect through rig-site utilization.
Pit shaft monitoring technology
The object of the invention is that providing a kind of contains H for height
2s/CO
2the gas field wellbore fluids composition monitoring system of gas field environmental quality design.To be solved by this invention raising difficult questions for discussion is: prior art is difficult to the position judging that sulphur deposits, be difficult to prediction pit shaft in along journey change of component rule and be difficult to predict H
2s/CO
2the series of problems of gas field pit shaft Multiphase Flow rule.
During first the present invention utilizes please number be 200910236674.0 patent " a kind of to containing H
2s/CO
2gas field wellbore fluids composition monitoring system and analytical approach thereof ", in analysis along under the conditions such as each change of component of pit shaft, sulphur deposition, change of flow state and thermal loss, set up high containing H
2s/CO
2gas field pit shaft Multiphase Flow law forecasting model;
The height of described foundation is containing H
2s/CO
2the step (these all describe in detail in original patent, so only briefly touch upon here) of gas field pit shaft Multiphase Flow law forecasting model comprises;
(1) comprehensive pressure-drop model
(2) thermograde model
And the foundation of (2) model (1):
Theoretical according to Van der Waals state equation, for multicomponent system at Wellbore Flow Feature Segmentation Modling model, foundation accurately can describe the state equation of gas, liquid PVT phase behavior under equilibrium state simultaneously, is then derived the computing formula describing gas, liquid temperature and pressure under equilibrium state by correlation formula.
Meeting the well section of super critical condition, high sulfur-containing mixture itself has much similar character to gas under Supercritical Conditions, therefore regards high sulfur-containing mixture as pressure gas.Utilize the theoretical foundation of high sulfur-containing gas dense gas thermodynamical model, by the interaction coefficient in adjustment state equation with preferably meet the fitting effect that rule improves thermodynamical model.Elementary sulfur physical dissolution process in high sulfur-containing gas considered by model, finally selects the empirical correlation model of high sulfur-containing gas, when pit shaft gathers temperature and pressure data compared with horn of plenty, carries out parameters revision.
(3) sulphur deposition forecast model
First assumed condition is proposed:
1. body is in semi-stability flow state;
2. formation temperature is constant;
3. constant flow;
4. stratum is level, uniform thickness and homogeneous, incompressible planar radial flow model.
Then, on the basis of above-mentioned hypothesis, the non-Darcy flow equation utilizing binomial equation to describe that Forhceimer proposes by experiment is adopted.Set up the distributed model of the deposition fraction of elementary sulfur in the acid gas reservoir performance history considering nonequilibrium process, model considers that the factors such as radial distance time are on the impact of sulphur deposition fraction; Subsequently on Elemental sulfur deposition distributed model basis, set up the computation model that Elemental sulfur deposition formation factor of porosity when considering nonequilibrium process, permeability, sulfur-bearing saturation degree and production limit time affect, and the model of nonequilibrium process is simplified, set up the computation model of corresponding equilibrium process.
Experimental studies have found that, along with temperature raises, H
2the saturated vapour pressure of S increases, and solubleness declines.Therefore at the saturated H of dissolution in low temperature
2after S, along with the rising of temperature then has a large amount of H in solution
2s separates out, and makes H
2the dividing potential drop of S increases.As shown in Figure 1.According to this understanding, the present invention is fully dissolved by low temperature, then the method for pressure build up, reaches simulation high sour gas well height H
2the requirement of S partial pressure conditions, overcomes classic method and uses merely supercharge pump supercharging, does not reach the required H of experiment
2the problem of S dividing potential drop.
Three models provide environmental parameter for concrete implementation step below above.
The concrete implementation step of the inventive method is as follows:
1, at room temperature H is utilized
2s gas cylinder passes into H in the high-temperature high-pressure reaction kettle of sealing
2s gas, passes into after about half a minute and stops;
2, H is treated
2s fully dissolves, and when the indicating gauge of high-temperature high-pressure reaction kettle shows pressure drop, again passes into H
2s gas,
3, repeatedly H is carried out
2s passes into-dissolves-pass into this cyclic process again, and make it dissolve and reach determined amounts;
4, heat temperature raising, makes H
2s dividing potential drop reaches the H specified
2s partial pressure conditions.
Carbon steel tubing and casing material corrosion performance speeding-up simulation evaluation method adjusts solution ph on the basis of simulated condition, makes test environment can reach maximum and ooze hydrogen saturation conditions, and according to site environment parameter, at High Temperature High Pressure height containing H
2s/CO
2environment is (because this method describes H
2s supercharging mode, CO
2supercharging does not have problems, so do not mention CO
2, in experiment, work as H
2after S dividing potential drop reaches preset value, logical CO in autoclave
2gas is to set pressure) under carry out the research of the performance such as corrosion coupon and stress corrosion.
Under high sour gas well environment, for carbon steel, carbon steel and low alloy steel based on hydrogen damage cracking, along with H
2the increase of S dividing potential drop, the diffusible hydrogen of sample is also in increase, but diffusible hydrogen has extreme value, i.e. a H
2s corrosion is oozed Hydrogen Energy and is enough reached capacity.When in sample can diffusible hydrogen reach capacity time, the damage that hydrogen causes sample is maximum.As shown in Figure 2.According to this understanding, the present invention is by the basis of simulated field working condition, and adjust solution ph, concrete implementation step is as follows:
1, prepare on-the-spot gas field recovered water solution (using analytical reagent and deionized water by Oil Field local water proportions), empirically aequum (amount of sample is crossed at energy end) adds in high-temperature high-pressure reaction kettle;
2, on the basis (temperature identical with work condition environment, force value) of simulated condition, adjust solution ph (with acid adjustment), make test environment can reach maximum and ooze hydrogen saturation conditions;
3, according to site environment parameter (main analog scene temperature and H
2s, CO
2dividing potential drop and whether exist sulphur deposition), at High Temperature High Pressure (H
2s dividing potential drop realizes realizing by step 4 method, CO
2dividing potential drop gas cylinder directly passes into airtight autoclave and can realize) high containing H
2s/CO
2the research such as corrosion coupon and stress corrosion is carried out under environment.
Described nickel-base alloy tubing and casing material corrosion performance speeding-up simulation evaluation method is on the basis of improving ambient temperature conditions, simulated field environmental parameter, at High Temperature High Pressure height containing H
2s/CO
2the research of the performance such as corrosion coupon and stress corrosion is carried out under environment;
Found by lot of experiments research, corrosion resistant alloy is mainly based on anodic solution, and temperature is the topmost factor affecting its corrosion.As Figure 3-Figure 4.Therefore when carrying out corrosion evaluation to nickel-base alloy, the basis of simulated condition raises the temperature of test environment, corrosion resistant alloy long service performance can be reflected like this, according to this understanding, the present invention is by the basis of simulated field working condition, improve test environment temperature, thus reach the experiment purpose accelerating carbon steel material corrosion process.
Concrete implementation step is as follows:
1, prepare the on-the-spot recovered water solution in gas field (pressing Oil Field local water proportions with analytical reagent and deionized water), empirically aequum (amount of sample is crossed at energy end) adds in high-temperature high-pressure reaction kettle;
2, on the basis of improving ambient temperature conditions (autoclave band heat riser), simulated field environmental parameter (analog temperature and H
2s/CO
2dividing potential drop and whether there is sulphur deposition), at High Temperature High Pressure height containing H
2s/CO
2the research such as corrosion coupon and stress corrosion is carried out under environment.
The evaluation method that above-mentioned experimental technique overcomes tradition simple simulation field working conditions condition can not meet the shortcoming of assessment material long service behavior at the scene, for the laboratory study of system and the material corrosion evaluated in high sour gas well environment provide a kind of effective way.
(2) Corrosion Evaluation system
The object of the present invention is to provide a set of high sour gas well tubing and casing material evaluation and preferred model and software.To carry out corrosion prediction and assessment for high sour gas well tubing and casing material, for high sour gas well High Temperature High Pressure height containing H
2s/CO
2the model designed etc. practical problems and software, for high sour gas well risk management provides effective technical support.Problem to be solved by this invention is that current material assessment and optimization model and software cannot meet the preferred demand of the on-the-spot material corrosion predicting and appraising of high sour gas well.
In order to realize foregoing invention object, the technical scheme of employing is as follows:
High sour gas well Corrosion Evaluation system, comprise corrosion rate forecast model and stress corrosion crack boundary model, and a set of Corrosion Evaluation software, corrosion rate forecast model and stress corrosion crack boundary model test existing Data Summary in the mass data and document obtained by the inventive method to obtain.Corrosion rate forecast model, by setting up the corrosion rate chart board under varying environment condition, can carry out forecast analysis to the corrosion rate of acid gas field typical case material, stress corrosion crack boundary model is according to temperature and H
2the change of S dividing potential drop, partition management has been carried out for the stress corrosion crack behavior of material under high sour gas well environment of typical nickel base alloy material, close the Failure Boundaries determining stress corrosion crack, Corrosion Evaluation software is based on corrosion prediction model, in conjunction with high sour gas well Field Production Data and corrosion-monitoring data, can be fast on-the-spot at high sour gas well, carry out critical material military service safety evaluation and preferably exactly, utilize Risk Management Framework realization to the expansion of safety evaluation and support simultaneously, certain booster action is played to the formulation of production technology scheme and improvement.The software system interface that the present invention adopts is directly perceived, and flexible operation, succinct, extensibility is strong.
(corrosion rate prediction chart board and stress corrosion crack boundary model are all sum up to obtain on the basis of lot of documents data and experimental data to described corrosion rate prediction chart board.Wherein a stress corrosion crack model part have employed international standard IS015156 result) be according to High Temperature High Pressure H
2s/CO
2corrosion experiment result, establishes H to typical drilling-production equipment material P110SS, solution strengthening nickel-base alloy G3,825
2s dividing potential drop-temperature, H
2s dividing potential drop-CO
2corrosion rate prediction chart board (as shown in Figure 5-Figure 7) of dividing potential drop and simple substance S-pH value.Utilize this chart board, can according to environmental parameter (as temperature, H
2s dividing potential drop, CO
2dividing potential drop, simple substance sulfur content, pH etc.) determine that material corrosion rate is in the present context interval, and then understand this material applicability in this context, corrosion rate prediction chart board, based on a large amount of test figures, can provide believable reference frame for the selection of acid-soluble oil field.
Described stress corrosion crack boundary model is on the basis of model in the past, according to High Temperature High Pressure H
2s/CO
2corrosion experiment result, determines at temperature and H
2failure Boundaries under S partial pressure conditions, after determining Sulfur releasing in addition, material is at temperature and H
2failure Boundaries under S partial pressure conditions, this model for nickel-base alloy G3,825,028 3 kind of material.
Fig. 8 is the element-free sulphur temperature of data acquisition and contraction Failure Boundaries of hydrogen sulfide sectional pressure when existing, wherein 0th district is interval all applicatory under other environmental baselines any specified in iso standard, i.e. less than 149 DEG C any hydrogen sulfide sectional pressures, less than 218 DEG C 2kPa hydrogen sulfide sectional pressures.1 border, district major part is determined by a large amount of experimental studies by laboratory, and in this district, G3 alloy does not ftracture in 30 days and Crack Extension do not occur yet, and shows that this district is comparatively safe.2nd district are then the synthesis result based on document and all kinds of test figure in the past, different with other environmental baselines owing to relating to test method, although the existing test in this district all shows that G3 did not ftracture or determines to have anti-SCC ability according to SSR test in 30 days, but when evaluating, still need further dedicated experiments to verify its security.3rd district owing to lacking test figure, and have exceeded critical temperature given in document, and therefore this district is unacceptable interval.
Fig. 9 is the temperature of data acquisition and the contraction Failure Boundaries of hydrogen sulfide sectional pressure when existing based on elementary sulfur.0th district is interval all applicatory under other environmental baselines any specified in iso standard, i.e. less than 149 DEG C any hydrogen sulfide sectional pressures.1 border, district is contracted to 180 DEG C according to test findings, and when this district's test findings is and there is elementary sulfur, alloy does not ftracture in 30 days and Crack Extension do not occur yet, and shows that this district is comparatively safe.2 district's outer boundaries are contracted to 0.7MPa H
2s and 204 DEG C, there is spot corrosion risk when sulfur content raises in this district, needs further verification experimental verification.3rd district are still unacceptable interval.
Described corrosion evaluation software systems comprise basic data library module, safety evaluation knowledge module, corrosion prediction analysis module and risk management module.
Wherein, basic data library module comprises field basic data, field monitoring data, indoor experimental data and data management system;
Safety evaluation knowledge module comprises H
2s/CO
2corrosion prediction model, high sour gas well corrosion failure case, height are containing H
2s/CO
2corrosion field related science document etc.
Corrosion prediction analysis module, according to the on-the-spot material of selected high sour gas well and environmental aspect, utilizes the corrosion evaluation model set up, evaluating material corrosive nature in this context and stress corrosion crack risk;
Risk management module comprises four submodules such as risk Source Analysis, hazards management, risk Metrics analysis and quantitative risk analysis.
This software is mainly as the interface that model uses, by inputting simple parameter, namely material applicability is under this condition calculated by background model, thus reaching the object of optimizing pipe string. its excess-three item comprises field basic data, safety evaluation knowledge and risk management module for reference when researcher provides basic data, theory preferred as material, and Figure 10 is software evaluation system composition structural drawing.
Embodiment:
Certain gas field, due to a point acid separator maintenance, makes acidifying solution enter gathering line.The research of described methods analyst is utilized to show: under the effect of corrosion inhibiter, the corrosion rate of carbon steel tubing is between 0.04-0.09.Belong to slight erosion.It is 0.058 that actual motion measures corrosion rate.This plays facilitation to this gas field trial throw product.
Described shaft column optimization of material method is applied to the selection of high sour gas well material and combines preferably, overbased acidic gas field different materials carries out analysis contrast, according to corrosion regularity and bimetallic corrosion feature, recommendation downhole temperature selects G3 compo pipe higher than 100 degree, 028 compo pipe can be selected lower than 100 degree, realize the combination of tubing string optimization of material, per tonly save 60,000 yuan, every mouthful of well can reduce expense 3,000,000 yuan, and whole oil-field development expense can reduce more than 100,000,000 yuan.The while of ensureing corrosion proof, economic benefits.
Described shaft column optimization of material method is also applied to the complex pipe technological project of certain nickel-base alloy G3 tubing production domesticization project, certain high sulfur resistive well head set-up production domesticization project, certain cast tube simultaneously.Wherein the production domesticization of G3 tubing makes external tubing price reduce to 480,000 yuan/ton by 620,000 yuan/ton then, and German W & M offers especially is recently 240,000 yuan/ton.Suppress external monopoly price and produce great economic benefit.Also the critical equipment application for applying under high Sulphur Contaminated Environment provides technical support.
The present invention is a kind of high sour gas well shaft column material optimizing evaluation system, particularly relates to one for height containing H
2s/CO
2the shaft column material optimizing evaluation method of gas field environmental quality design, comprises high sour gas well fluid flowing law monitoring means, wellbore materials corrosion evaluation unit and Corrosion Evaluation predicting unit.Carry out system evaluation and preferably from environmental parameter analysis, corrosion evaluation method and corrosion prediction three aspect, material optimizing evaluation system of the present invention can be used in High Temperature High Pressure height containing H
2s/CO
2material corrosion evaluation under severe rugged environment and preferably, usable range more extensively, also more reliable.This invention solves high containing H
2s/CO
2gas field is because lacking corrosion simulated evaluation method and corrosion prediction model and software targetedly, and selection lacks a difficult problem for foundation, for high sour gas well exploitation and safety in production provide theory support.
Along with deepening continuously of acid gas field development process, the exploitation share of high sour gas well is increasing, the gasser that need carry out Material selec-tion and corrosion prediction for high sour gas well environment both at home and abroad can get more and more, and therefore this invention at home and abroad all has broad application prospects.
Technique scheme is one embodiment of the present invention, for those skilled in the art, on the basis that the invention discloses application process and principle, be easy to make various types of improvement or distortion, and the method be not limited only to described by the above-mentioned embodiment of the present invention, therefore previously described mode is just preferred, and does not have restrictive meaning.
Claims (6)
1. a high sour gas well shaft column material optimizing evaluation system, is characterized in that: described system comprises corrosion rate forecast model and stress corrosion crack boundary model;
Described corrosion rate forecast model comprises H
2s dividing potential drop-temperature, H
2s dividing potential drop-CO
2the corrosion rate prediction chart board of dividing potential drop and simple substance S-pH value;
Described stress corrosion crack boundary model comprises material at temperature and H
2after Failure Boundaries under S partial pressure conditions and Sulfur releasing, material is at temperature and H
2failure Boundaries under S partial pressure conditions.
2. high sour gas well shaft column material optimizing evaluation method according to claim 1, is characterized in that: described method comprises:
Determine environmental baseline and parameter;
At high H
2under S partial pressure conditions, speeding-up simulation test is carried out to the material corrosion performance of nickel-base alloy tubing and casing;
At high H
2under S partial pressure conditions, speeding-up simulation test is carried out to the corrosive nature of carbon steel tubing and casing material.
3. high sour gas well shaft column material optimizing evaluation method according to claim 2, is characterized in that: describedly determine that environmental baseline and parameter are achieved in that
Analyzing along under the condition of each change of component of pit shaft, sulphur deposition, change of flow state and thermal loss, set up high containing H
2s/CO
2gas field pit shaft Multiphase Flow law forecasting model, described forecast model comprises comprehensive pressure-drop model, thermograde model and sulphur deposition forecast model.
4. high sour gas well shaft column material optimizing evaluation method according to claim 3, is characterized in that: described at high H
2carry out speeding-up simulation test to the material corrosion performance of nickel-base alloy tubing and casing under S partial pressure conditions to be achieved in that
1, prepare on-the-spot gas field recovered water solution, empirically aequum adds in high-temperature high-pressure reaction kettle;
2, on the basis ensureing the temperature and pressure value identical with work condition environment, adjust the pH value of described solution, make test environment reach maximum and ooze hydrogen saturation conditions;
3, according to site environment parameter, at High Temperature High Pressure height containing H
2s/CO
2the research of corrosion coupon and stress corrosion is carried out under environment.
5. high sour gas well shaft column material optimizing evaluation method according to claim 3, is characterized in that: described at high H
2carry out speeding-up simulation test to the corrosive nature of carbon steel tubing and casing material under S partial pressure conditions to be achieved in that
1, prepare the on-the-spot recovered water solution in gas field, empirically aequum adds in high-temperature high-pressure reaction kettle;
2, on the basis of improving ambient temperature conditions, according to site environment parameter, at High Temperature High Pressure height containing H
2s/CO
2the research of corrosion coupon and stress corrosion is carried out under environment.
6. the high sour gas well shaft column material optimizing evaluation method according to claim 4 or 5, is characterized in that: described height is containing H
2s/CO
2environment is achieved in that
1, at room temperature H is utilized
2s gas cylinder passes into H in the high-temperature high-pressure reaction kettle of sealing
2s gas;
2, H is treated
2s fully dissolves, and when the indicating gauge of high-temperature high-pressure reaction kettle shows pressure drop, again passes into H
2s gas;
3, repeatedly H is carried out
2s passes into-dissolves-pass into this cyclic process again, and make it dissolve and reach determined amounts;
4, heat temperature raising, makes H
2s dividing potential drop reaches the H specified
2s partial pressure conditions;
5, with gas cylinder directly by CO
2pass into airtight high-temperature high-pressure reaction kettle, stop after reaching set pressure.
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