US2437475A - Method of mitigating corrosion in wells - Google Patents
Method of mitigating corrosion in wells Download PDFInfo
- Publication number
- US2437475A US2437475A US632862A US63286245A US2437475A US 2437475 A US2437475 A US 2437475A US 632862 A US632862 A US 632862A US 63286245 A US63286245 A US 63286245A US 2437475 A US2437475 A US 2437475A
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- US
- United States
- Prior art keywords
- well
- corrosion
- tubing
- wells
- ion exchange
- 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.)
- Expired - Lifetime
Links
- 238000005260 corrosion Methods 0.000 title description 21
- 230000007797 corrosion Effects 0.000 title description 21
- 230000000116 mitigating effect Effects 0.000 title description 7
- 238000000034 method Methods 0.000 title description 6
- 229930195733 hydrocarbon Natural products 0.000 description 21
- 150000002430 hydrocarbons Chemical class 0.000 description 21
- 239000004215 Carbon black (E152) Substances 0.000 description 17
- 238000005342 ion exchange Methods 0.000 description 14
- 239000000463 material Substances 0.000 description 13
- 239000000470 constituent Substances 0.000 description 11
- 239000003463 adsorbent Substances 0.000 description 9
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 9
- 150000001768 cations Chemical class 0.000 description 6
- 238000004519 manufacturing process Methods 0.000 description 6
- 150000007524 organic acids Chemical class 0.000 description 6
- XEEYBQQBJWHFJM-UHFFFAOYSA-N Iron Chemical compound [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 description 5
- 235000005985 organic acids Nutrition 0.000 description 5
- 239000003208 petroleum Substances 0.000 description 5
- 150000001450 anions Chemical class 0.000 description 4
- 150000003839 salts Chemical class 0.000 description 4
- QTBSBXVTEAMEQO-UHFFFAOYSA-N Acetic acid Chemical compound CC(O)=O QTBSBXVTEAMEQO-UHFFFAOYSA-N 0.000 description 3
- OYPRJOBELJOOCE-UHFFFAOYSA-N Calcium Chemical compound [Ca] OYPRJOBELJOOCE-UHFFFAOYSA-N 0.000 description 3
- FYYHWMGAXLPEAU-UHFFFAOYSA-N Magnesium Chemical class [Mg] FYYHWMGAXLPEAU-UHFFFAOYSA-N 0.000 description 3
- HEMHJVSKTPXQMS-UHFFFAOYSA-M Sodium hydroxide Chemical compound [OH-].[Na+] HEMHJVSKTPXQMS-UHFFFAOYSA-M 0.000 description 3
- 239000002253 acid Substances 0.000 description 3
- 230000015572 biosynthetic process Effects 0.000 description 3
- 238000009835 boiling Methods 0.000 description 3
- 229910052791 calcium Inorganic materials 0.000 description 3
- 239000011575 calcium Substances 0.000 description 3
- 238000006243 chemical reaction Methods 0.000 description 3
- 229910052742 iron Inorganic materials 0.000 description 3
- 229910052749 magnesium Inorganic materials 0.000 description 3
- 239000011777 magnesium Substances 0.000 description 3
- 150000007522 mineralic acids Chemical class 0.000 description 3
- 239000003921 oil Substances 0.000 description 3
- CDBYLPFSWZWCQE-UHFFFAOYSA-L Sodium Carbonate Chemical compound [Na+].[Na+].[O-]C([O-])=O CDBYLPFSWZWCQE-UHFFFAOYSA-L 0.000 description 2
- 229910001413 alkali metal ion Inorganic materials 0.000 description 2
- 239000007789 gas Substances 0.000 description 2
- -1 iron cation Chemical class 0.000 description 2
- 239000007788 liquid Substances 0.000 description 2
- 229910052751 metal Inorganic materials 0.000 description 2
- 239000002184 metal Substances 0.000 description 2
- BDAGIHXWWSANSR-UHFFFAOYSA-N methanoic acid Natural products OC=O BDAGIHXWWSANSR-UHFFFAOYSA-N 0.000 description 2
- 230000001172 regenerating effect Effects 0.000 description 2
- 229920005989 resin Polymers 0.000 description 2
- 239000011347 resin Substances 0.000 description 2
- 239000010457 zeolite Substances 0.000 description 2
- FWLHAQYOFMQTHQ-UHFFFAOYSA-N 2-N-[8-[[8-(4-aminoanilino)-10-phenylphenazin-10-ium-2-yl]amino]-10-phenylphenazin-10-ium-2-yl]-8-N,10-diphenylphenazin-10-ium-2,8-diamine hydroxy-oxido-dioxochromium Chemical compound O[Cr]([O-])(=O)=O.O[Cr]([O-])(=O)=O.O[Cr]([O-])(=O)=O.Nc1ccc(Nc2ccc3nc4ccc(Nc5ccc6nc7ccc(Nc8ccc9nc%10ccc(Nc%11ccccc%11)cc%10[n+](-c%10ccccc%10)c9c8)cc7[n+](-c7ccccc7)c6c5)cc4[n+](-c4ccccc4)c3c2)cc1 FWLHAQYOFMQTHQ-UHFFFAOYSA-N 0.000 description 1
- OSWFIVFLDKOXQC-UHFFFAOYSA-N 4-(3-methoxyphenyl)aniline Chemical compound COC1=CC=CC(C=2C=CC(N)=CC=2)=C1 OSWFIVFLDKOXQC-UHFFFAOYSA-N 0.000 description 1
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 description 1
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 description 1
- DGAQECJNVWCQMB-PUAWFVPOSA-M Ilexoside XXIX Chemical compound C[C@@H]1CC[C@@]2(CC[C@@]3(C(=CC[C@H]4[C@]3(CC[C@@H]5[C@@]4(CC[C@@H](C5(C)C)OS(=O)(=O)[O-])C)C)[C@@H]2[C@]1(C)O)C)C(=O)O[C@H]6[C@@H]([C@H]([C@@H]([C@H](O6)CO)O)O)O.[Na+] DGAQECJNVWCQMB-PUAWFVPOSA-M 0.000 description 1
- ISWSIDIOOBJBQZ-UHFFFAOYSA-N Phenol Chemical compound OC1=CC=CC=C1 ISWSIDIOOBJBQZ-UHFFFAOYSA-N 0.000 description 1
- 229910021536 Zeolite Inorganic materials 0.000 description 1
- 230000002378 acidificating effect Effects 0.000 description 1
- 150000007513 acids Chemical class 0.000 description 1
- 239000003513 alkali Substances 0.000 description 1
- 238000005349 anion exchange Methods 0.000 description 1
- IWLBIFVMPLUHLK-UHFFFAOYSA-N azane;formaldehyde Chemical compound N.O=C IWLBIFVMPLUHLK-UHFFFAOYSA-N 0.000 description 1
- 239000003575 carbonaceous material Substances 0.000 description 1
- 238000005341 cation exchange Methods 0.000 description 1
- 239000004568 cement Substances 0.000 description 1
- 239000003795 chemical substances by application Substances 0.000 description 1
- 239000003245 coal Substances 0.000 description 1
- 238000009833 condensation Methods 0.000 description 1
- 230000005494 condensation Effects 0.000 description 1
- 239000010779 crude oil Substances 0.000 description 1
- 230000001419 dependent effect Effects 0.000 description 1
- HNPSIPDUKPIQMN-UHFFFAOYSA-N dioxosilane;oxo(oxoalumanyloxy)alumane Chemical compound O=[Si]=O.O=[Al]O[Al]=O HNPSIPDUKPIQMN-UHFFFAOYSA-N 0.000 description 1
- 239000010459 dolomite Substances 0.000 description 1
- 229910000514 dolomite Inorganic materials 0.000 description 1
- 239000000975 dye Substances 0.000 description 1
- 239000012530 fluid Substances 0.000 description 1
- WSFSSNUMVMOOMR-UHFFFAOYSA-N formaldehyde Substances O=C WSFSSNUMVMOOMR-UHFFFAOYSA-N 0.000 description 1
- SLGWESQGEUXWJQ-UHFFFAOYSA-N formaldehyde;phenol Chemical compound O=C.OC1=CC=CC=C1 SLGWESQGEUXWJQ-UHFFFAOYSA-N 0.000 description 1
- 235000019253 formic acid Nutrition 0.000 description 1
- 229910001385 heavy metal Inorganic materials 0.000 description 1
- 239000001257 hydrogen Substances 0.000 description 1
- 229910052739 hydrogen Inorganic materials 0.000 description 1
- 229910000037 hydrogen sulfide Inorganic materials 0.000 description 1
- 230000007062 hydrolysis Effects 0.000 description 1
- 238000006460 hydrolysis reaction Methods 0.000 description 1
- 230000003301 hydrolyzing effect Effects 0.000 description 1
- GPRLSGONYQIRFK-UHFFFAOYSA-N hydron Chemical compound [H+] GPRLSGONYQIRFK-UHFFFAOYSA-N 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-M hydroxide Chemical compound [OH-] XLYOFNOQVPJJNP-UHFFFAOYSA-M 0.000 description 1
- 229910052588 hydroxylapatite Inorganic materials 0.000 description 1
- 238000011065 in-situ storage Methods 0.000 description 1
- 229910017053 inorganic salt Inorganic materials 0.000 description 1
- 239000003077 lignite Substances 0.000 description 1
- 150000001457 metallic cations Chemical class 0.000 description 1
- 239000003129 oil well Substances 0.000 description 1
- 239000002245 particle Substances 0.000 description 1
- 239000003415 peat Substances 0.000 description 1
- XYJRXVWERLGGKC-UHFFFAOYSA-D pentacalcium;hydroxide;triphosphate Chemical compound [OH-].[Ca+2].[Ca+2].[Ca+2].[Ca+2].[Ca+2].[O-]P([O-])([O-])=O.[O-]P([O-])([O-])=O.[O-]P([O-])([O-])=O XYJRXVWERLGGKC-UHFFFAOYSA-D 0.000 description 1
- 239000012071 phase Substances 0.000 description 1
- 229920001568 phenolic resin Polymers 0.000 description 1
- 150000002989 phenols Chemical class 0.000 description 1
- 229920000767 polyaniline Polymers 0.000 description 1
- 230000002265 prevention Effects 0.000 description 1
- 230000002035 prolonged effect Effects 0.000 description 1
- 230000008929 regeneration Effects 0.000 description 1
- 238000011069 regeneration method Methods 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 229920006395 saturated elastomer Polymers 0.000 description 1
- 150000004760 silicates Chemical class 0.000 description 1
- 229910052708 sodium Inorganic materials 0.000 description 1
- 239000011734 sodium Substances 0.000 description 1
- 229910000029 sodium carbonate Inorganic materials 0.000 description 1
- 235000011121 sodium hydroxide Nutrition 0.000 description 1
- 150000003467 sulfuric acid derivatives Chemical class 0.000 description 1
- 239000012808 vapor phase Substances 0.000 description 1
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/02—Subsoil filtering
- E21B43/08—Screens or liners
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B37/00—Methods or apparatus for cleaning boreholes or wells
- E21B37/06—Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting, e.g. eliminating, the deposition of paraffins or like substances
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC
- Y10S—TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y10S166/00—Wells
- Y10S166/902—Wells for inhibiting corrosion or coating
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC
- Y10S—TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y10S507/00—Earth boring, well treating, and oil field chemistry
- Y10S507/939—Corrosion inhibitor
Definitions
- 'Ihe completion of a well for the production of petroleum hydrocarbons generally comprises set- 5 and iron. These materials in the presence of water and under elevated temperatures as encountered in wells may undergo hydrolysis to form the corresponding'inorganic acids which are capable of attacking well tubing. In other cases hydrogen sulfide dissolved in water carried by the hydrocarbon stream may be effective to promote corrosion of metal parts.
- an ion exchange material adapted to react with the corrosive constituent is introduced into the well and brought into cpntact with the hydrocarbon flow streamto remove the corrosive constituent therefrom by ion exchange reaction before it has had the opportunity to attack the well tubing appreciably.
- ananion exchange material or a cation exchanger, or both may be employed dependent upon what the particular constituent is that is apt to cause the corrosion.
- an anion exchange material capable of replacing theaeid/ anion by an hydroxyl ion may be usedrf'nion exchangers suitable for this purpose'are well known and include resins such as amine-formaldehyde, basic dyestuff such as aniline black, natural inorganic adsorbents such as hydroxyapatite and dolomite 'and synthetic heavy-metal silicates.
- resins such as amine-formaldehyde, basic dyestuff such as aniline black, natural inorganic adsorbents such as hydroxyapatite and dolomite 'and synthetic heavy-metal silicates.
- Such exchangers may also be employed where aqueousA hydrogen sul. de or phenol is the cause of corrosion.
- tubing within the casing and, after the well has on' the upper part of the casing so as not to subl0 ject it to the pressure of the productive zone.
- the casing often is placed through the productive zone and the bottom of the casing is sealed off by means of cement. the well then being opened up for production by gun perforation of the casing adjacent the oil stratum. The 'well is then permitted to produce through the tubing.
- the hydrolyzable salts may, if desired, be removed by contacting the flow stream rst with a cation exchanger capable of substituting the hydrogen ion for the metallic cation and immediately lthereafter with an anion exchanger to remove the resulting inorganic acid.
- Cation exchangers suitable as the rst Contact material include resins such as tannin-formaldehyde and phenol-formaldehyde, certain phenolic sulfonic acid derivatives and sulfonated carbonaceous materials such as coal, lignite and peat.
- a container I1 made of perforated sheet metal or plastic material or of heavy wire screen is positioned within the well tubing Il and contains an ion exchange material adapted to remove the corrosive constituent from the flow stream.
- the upper portion of container I1 is designed so that the container may be lowered into or withdrawn from the tubing on a conventional wire line and is provided with a locking device I 9 which may be of any known or suitable type for securing the container in place within the tubing.
- the hydrocarbon stream flows from the productive zone II 1 through casing perforations I3 and into the tubing through perforations 20. thence into thecontainer I1 wherein the ilow stream comes in intimate contact with the ion exchange material or adsorbent I8, whereby the corrosive constituent is removed by ion exchange reaction.
- the adsorbent Afterfthe adsorbent has been used for suillcient time to become saturated and lose its effectiveness for further removal of the corrosive constituent, it may be regenerated in situ by shutting off the well flow; injecting into the tubing a regenerating solution and permitting the solution to contact the adsorbent.
- a solution of suitable alkali such as sodium carbonate or caustic soda, may be used as the regenerating agent.
- suitable alkali such as sodium carbonate or caustic soda
- regeneration maybe effected by an acid solution.
- the container I1 may be periodicallyremoved from the well and the used adsorbent replaced by freshmaterial.
- the method of mitigating such corrosion which 'comprises placingf within the well a granular mass of ion exchange material adapted to remove the corrosive constituent from the hydrocarbon stream by ion exchange reaction, and bringing the hydrocarbon stream in contact with the ion exchange material to remove said constituent.
- the method of mitigating such corrosion which comprises placing withinthe well a granular mass of anion Iexchange materiall adapted to react y.by ion exchange with such organic acids, bringing the hydrocarbon stream in contact with the ion exchange material and thereby removing said organic acids.
- the method of mitigating such corrosion which comprises placing within the well a granular mass of. cation exchange material adapted to exchange an alkali metal ion for the cation of said salt, and bringing the hydrocarbon stream in contact with the ion exchange material to eiect the ion exchange.
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- Life Sciences & Earth Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Geology (AREA)
- Engineering & Computer Science (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Chemical & Material Sciences (AREA)
- General Chemical & Material Sciences (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
Description
ting a casing in the borehole, inserting a string of been flushed with water, placing a packer in the annulus between the casing and tubing to close V temperatures are lower.
i trained by the hydrocarbon stream, and during UNITED sTATEs PATENT OFFICE METHOD F MITIGATING CORROSION IN WELLS William F. Oxford, Jr., Beaumont, Tex.,-as,signor l to Sun Oil Company, Philadelphia,v Pa., a corporation of New Jersey Y Application December 5, 1945, Serial No. 632,862
1 3 Claims. (Cl. 252-8.55) This invention relates to petroleum production and particularly has to do with the prevention or mitigation of corrosion in oil and gas Wells.
'Ihe completion of a well for the production of petroleum hydrocarbons generally comprises set- 5 and iron. These materials in the presence of water and under elevated temperatures as encountered in wells may undergo hydrolysis to form the corresponding'inorganic acids which are capable of attacking well tubing. In other cases hydrogen sulfide dissolved in water carried by the hydrocarbon stream may be effective to promote corrosion of metal parts.
'Ihe present invention is directed to overcoming corrosion problems of the above indicated type and provides a method of preventing or mitigating such corrosion. According to the invention, an ion exchange material adapted to react with the corrosive constituent is introduced into the well and brought into cpntact with the hydrocarbon flow streamto remove the corrosive constituent therefrom by ion exchange reaction before it has had the opportunity to attack the well tubing appreciably. Either` ananion exchange material or a cation exchanger, or both, may be employed dependent upon what the particular constituent is that is apt to cause the corrosion. For example, in gas-distillate wells where the relatively low boiling organic acids are the cause, an anion exchange material capable of replacing theaeid/ anion by an hydroxyl ion may be usedrf'nion exchangers suitable for this purpose'are well known and include resins such as amine-formaldehyde, basic dyestuff such as aniline black, natural inorganic adsorbents such as hydroxyapatite and dolomite 'and synthetic heavy-metal silicates. Such exchangers may also be employed where aqueousA hydrogen sul. de or phenol is the cause of corrosion.
tubing within the casing and, after the well has on' the upper part of the casing so as not to subl0 ject it to the pressure of the productive zone. The casing often is placed through the productive zone and the bottom of the casing is sealed off by means of cement. the well then being opened up for production by gun perforation of the casing adjacent the oil stratum. The 'well is then permitted to produce through the tubing.
It has been foundv that in certain cases the well tubing is subjected to corrosion due to corrosive constituents that are carried in the` hydrocarbon flow stream. While this is not so often the case in wells producing crude oil, it has been found to be particularly true in high pressure gasdistillate` wells wherein the main part oi the hydrocarbon ow is in the vapor phase. The hydrocarbon vapors carry along appreciable. amounts of water which in the lower portion ofthe well may be entirely in vapor form due tothe higher prevailing temperatures or 'the water mayV f be present as finely divided liquid particles especlallyl ign/,the upper part of the well where the Corrosion in gas-distillate wells has been noted to occur especially severely in the upper portion of the wells (as also inthe well fittings and ilow lines), perhaps being coextensive with the zone wherein the temperature is sufllciently low that water can be present in liquid state.
It has now been found Vthat the corrosion in gas-distillate wells is due largely to the presence of small but appreciable amounts of low boiling organic acids, such as formic acid, acetic acid. propionlc acid, etc.. whichare carried along by the hydrocarbon ilow. These acids are present in the water which condenses froml or is ension results from the presence of hydrolyzable inorganic salts of magnesium. calcium or iron in the water carried by the iiow stream, a cation exchangerv may be'used which is capable of removing the magnesium, calcium or iron cation and replacing it by an alkali metal ion such as sodium. Known exchangers ofthis type are the zeolites which include processed green sand and synthetic gel zeolite. Alternatively, the hydrolyzable salts may, if desired, be removed by contacting the flow stream rst with a cation exchanger capable of substituting the hydrogen ion for the metallic cation and immediately lthereafter with an anion exchanger to remove the resulting inorganic acid. Cation exchangers suitable as the rst Contact material include resins such as tannin-formaldehyde and phenol-formaldehyde, certain phenolic sulfonic acid derivatives and sulfonated carbonaceous materials such as coal, lignite and peat.
the course of prolonged operation of the well are capable of causing extremely severecorrosion of the well tubing, ttings and flow lines. Other acidic constituents which are encountered in some gas producing wells and which likewise may be corrosive are phenolic compounds.
In some cases corrosion of well tubing may re, sult from the presence of inorganic salts such as the sulfates or chloridesof magnesium, calcium On the other hand, in cases Where thecorrof`Y The accompanying drawing, which illustrates a mode of carrying out the invention, is a diagrammatic vertical sectional view of the lower portion of an oil well.
In the drawing, I vrepresents a lower portion of the well casing which extends down through A the productive formation II into the formation tubing I4 extending below the packer I 5 has.
perforations to permit the ow of fluids from the productive formation into the tubing and the end of the tubing is closed as shown at I 6'. A container I1 made of perforated sheet metal or plastic material or of heavy wire screen is positioned within the well tubing Il and contains an ion exchange material adapted to remove the corrosive constituent from the flow stream. The upper portion of container I1 is designed so that the container may be lowered into or withdrawn from the tubing on a conventional wire line and is provided with a locking device I 9 which may be of any known or suitable type for securing the container in place within the tubing.
With the arrangement as shown, the hydrocarbon stream flows from the productive zone II 1 through casing perforations I3 and into the tubing through perforations 20. thence into thecontainer I1 wherein the ilow stream comes in intimate contact with the ion exchange material or adsorbent I8, whereby the corrosive constituent is removed by ion exchange reaction. Afterfthe adsorbent has been used for suillcient time to become saturated and lose its effectiveness for further removal of the corrosive constituent, it may be regenerated in situ by shutting off the well flow; injecting into the tubing a regenerating solution and permitting the solution to contact the adsorbent. Where the adsorbent is an anion exchanger, a solution of suitable alkali, such as sodium carbonate or caustic soda, may be used as the regenerating agent. In the case of cation exchangers regeneration maybe effected by an acid solution. Also, if desired, the container I1 may be periodicallyremoved from the well and the used adsorbent replaced by freshmaterial.
It will be understood that the above described embodini'ent is merely illustrative ofone means of practicing the invention and that many modications maybe made within the scope of the invention. For example, in dually completed wells wherein `the well is permitted to produce from one horizon through the tubing while also producing from another horizon through the annular space between tubing and casing, corrosion within the tubing may be mitigated in the manner abovedescribed while corrosion of the outer surface cf the tubingv and inner surface of the casing may be prevented by suitably positioningl a batch of the ion exchange adsorbent in the annular space to contact the hydrocarbon now therein. Again, in cases where corrosion is apt to occur only in the upper part of the well, it may be desirable to place the adsorbent at an upper level in the well rather than near the bottom of the tubing. For example, in high pressure gas-distillate wells it has been observed that most of the corrosion occurs at depths above 3000 feet; evidently because it is only .within this shallower zone that the temperature is suiliciently low that water carried by the hydrocarbon vapors can condense and form an aqueous organic acid phase. In such cases it may be desirable to place the ion exchange adsorbent near the lower edge of this zone where condensation first occurs.
`What I claim and desire to protect by Letters Patent is:
1. In the production of petroleum hydrocarbons through a 'well .wherein the hydrocarbon flow stream contains a constituent tending to cause corrosion of the well tubing, the method of mitigating such corrosion which 'comprises placingf within the well a granular mass of ion exchange material adapted to remove the corrosive constituent from the hydrocarbon stream by ion exchange reaction, and bringing the hydrocarbon stream in contact with the ion exchange material to remove said constituent. Y
2. In the production of petroleum hydrocarbons through a gas-distillate well wherein the hydrocarbon flow stream contains low boiling organic acids which tend to cause corrosion of the well tubing, the method of mitigating such corrosion which comprises placing withinthe well a granular mass of anion Iexchange materiall adapted to react y.by ion exchange with such organic acids, bringing the hydrocarbon stream in contact with the ion exchange material and thereby removing said organic acids.
3. In the production of petroleum hydrocarbons through a well wherein the hydrocarbon flow stream contains an inorganic salt capable of hydrolyzing to form an inorganic acid corrosive to the well tubing, the method of mitigating such corrosion which comprises placing within the well a granular mass of. cation exchange material adapted to exchange an alkali metal ion for the cation of said salt, and bringing the hydrocarbon stream in contact with the ion exchange material to eiect the ion exchange.
' WILLIAM F. OXFORD, JR.
REFERENCES CITED The following references are of record in the file of this patent:
UNITED STATES PATENTS Number Name Date 1,829,705 Walker I Oct. 27, 1931 1,873,084 Walker II Aug. 23, 1932 2,226,134 lLiebknecht et al. Dec. 24, 1940 2,357,559 Smith Sept, 5, 1944- 2,360,195 Brittin Oct, 10, 1944 2,366,008 DAlelio Dec. 26, 1944 2,388,235 Bowman et al Nov. 6, 1945
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
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US632862A US2437475A (en) | 1945-12-05 | 1945-12-05 | Method of mitigating corrosion in wells |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US632862A US2437475A (en) | 1945-12-05 | 1945-12-05 | Method of mitigating corrosion in wells |
Publications (1)
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US2437475A true US2437475A (en) | 1948-03-09 |
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US632862A Expired - Lifetime US2437475A (en) | 1945-12-05 | 1945-12-05 | Method of mitigating corrosion in wells |
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Cited By (21)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US2496594A (en) * | 1947-09-11 | 1950-02-07 | Cities Service Oil Co | Formaldehyde corrosion inhibitor compositions |
US2496595A (en) * | 1947-09-11 | 1950-02-07 | Cities Service Oil Co | Formaldehyde corrosion inhibitor compositions |
US2635996A (en) * | 1951-03-16 | 1953-04-21 | California Research Corp | Corrosion inhibitor |
US2717651A (en) * | 1952-07-22 | 1955-09-13 | California Research Corp | Apparatus for preventing corrosion in oil wells |
US2728400A (en) * | 1952-07-22 | 1955-12-27 | California Research Corp | Apparatus for preventing corrosion in oil wells |
US2760584A (en) * | 1952-07-22 | 1956-08-28 | California Research Corp | Method and apparatus for preventing corrosion in oil wells |
US3412798A (en) * | 1967-07-10 | 1968-11-26 | Jerry K. Gregston | Method and apparatus for treating gas lift wells |
US3473611A (en) * | 1968-10-04 | 1969-10-21 | Jerry K Gregston | Method for treating gas lift wells |
US4779679A (en) * | 1987-11-18 | 1988-10-25 | Mobil Oil Corporation | Method for scale and corrosion inhibition in a well penetrating a subterranean formation |
US4787455A (en) * | 1987-11-18 | 1988-11-29 | Mobil Oil Corporation | Method for scale and corrosion inhibition in a well penetrating a subterranean formation |
US4789031A (en) * | 1987-05-22 | 1988-12-06 | Walker Claud W | Gas anchor and treating device |
WO1992009786A1 (en) * | 1990-11-28 | 1992-06-11 | Mobil Oil Corporation | A method for dissolution and removal of alkaline earth metal scales |
US5758725A (en) * | 1996-05-06 | 1998-06-02 | Streetman; Foy | Method and device for enhancing oil and gas flow in a well |
US20060011345A1 (en) * | 2004-07-15 | 2006-01-19 | Delaloye Richard J | Method and apparatus for downhole artificial lift system protection |
US20110162841A1 (en) * | 2009-12-11 | 2011-07-07 | Conocophillips Company | Continuous Slow Dissolving Chemical Treatment for Oil and Gas Wells |
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US9097093B1 (en) | 2012-01-06 | 2015-08-04 | Cavin B. Frost | Downhole chemical treatment assembly for use in a downhole wellbore |
US9097094B1 (en) | 2012-01-06 | 2015-08-04 | Cavin B. Frost | Method for chemically treating hydrocarbon fluid in a downhole wellbore |
US10081758B2 (en) | 2015-12-04 | 2018-09-25 | Ecolab Usa Inc. | Controlled release solid scale inhibitors |
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US2496594A (en) * | 1947-09-11 | 1950-02-07 | Cities Service Oil Co | Formaldehyde corrosion inhibitor compositions |
US2496595A (en) * | 1947-09-11 | 1950-02-07 | Cities Service Oil Co | Formaldehyde corrosion inhibitor compositions |
US2496596A (en) * | 1947-09-11 | 1950-02-07 | Cities Service Oil Co | Formaldehyde corrosion inhibitor compositions |
US2635996A (en) * | 1951-03-16 | 1953-04-21 | California Research Corp | Corrosion inhibitor |
US2760584A (en) * | 1952-07-22 | 1956-08-28 | California Research Corp | Method and apparatus for preventing corrosion in oil wells |
US2728400A (en) * | 1952-07-22 | 1955-12-27 | California Research Corp | Apparatus for preventing corrosion in oil wells |
US2717651A (en) * | 1952-07-22 | 1955-09-13 | California Research Corp | Apparatus for preventing corrosion in oil wells |
US3412798A (en) * | 1967-07-10 | 1968-11-26 | Jerry K. Gregston | Method and apparatus for treating gas lift wells |
US3473611A (en) * | 1968-10-04 | 1969-10-21 | Jerry K Gregston | Method for treating gas lift wells |
US4789031A (en) * | 1987-05-22 | 1988-12-06 | Walker Claud W | Gas anchor and treating device |
US4779679A (en) * | 1987-11-18 | 1988-10-25 | Mobil Oil Corporation | Method for scale and corrosion inhibition in a well penetrating a subterranean formation |
US4787455A (en) * | 1987-11-18 | 1988-11-29 | Mobil Oil Corporation | Method for scale and corrosion inhibition in a well penetrating a subterranean formation |
WO1992009786A1 (en) * | 1990-11-28 | 1992-06-11 | Mobil Oil Corporation | A method for dissolution and removal of alkaline earth metal scales |
US5758725A (en) * | 1996-05-06 | 1998-06-02 | Streetman; Foy | Method and device for enhancing oil and gas flow in a well |
US20060011345A1 (en) * | 2004-07-15 | 2006-01-19 | Delaloye Richard J | Method and apparatus for downhole artificial lift system protection |
WO2006019546A1 (en) * | 2004-07-15 | 2006-02-23 | Weatherford/Lamb, Inc. | Method and apparatus for downhole artificial lift system protection |
GB2429739A (en) * | 2004-07-15 | 2007-03-07 | Weatherford Lamb | Method and apparatus for downhole artificial lift system protection |
US7195070B2 (en) | 2004-07-15 | 2007-03-27 | Weatherford/Lamb, Inc. | Method and apparatus for downhole artificial lift system protection |
US20070227737A1 (en) * | 2004-07-15 | 2007-10-04 | Weatherford/Lamb, Inc. | Method and apparatus for downhole artificial lift system protection |
US7503389B2 (en) | 2004-07-15 | 2009-03-17 | Delaloye Richard J | Method and apparatus for downhole artificial lift system protection |
US20090133882A1 (en) * | 2004-07-15 | 2009-05-28 | Delaloye Richard J | Method and apparatus for downhole artificial lift system protection |
GB2429739B (en) * | 2004-07-15 | 2009-12-30 | Weatherford Lamb | Method and apparatus for downhole artificial lift system protection |
US20110162841A1 (en) * | 2009-12-11 | 2011-07-07 | Conocophillips Company | Continuous Slow Dissolving Chemical Treatment for Oil and Gas Wells |
US8950491B2 (en) | 2012-01-06 | 2015-02-10 | Odessa Separator, Inc. | Downhole assembly for treating wellbore components, and method for treating a wellbore |
US9097093B1 (en) | 2012-01-06 | 2015-08-04 | Cavin B. Frost | Downhole chemical treatment assembly for use in a downhole wellbore |
US9097094B1 (en) | 2012-01-06 | 2015-08-04 | Cavin B. Frost | Method for chemically treating hydrocarbon fluid in a downhole wellbore |
US10081758B2 (en) | 2015-12-04 | 2018-09-25 | Ecolab Usa Inc. | Controlled release solid scale inhibitors |
US10865339B2 (en) | 2016-05-16 | 2020-12-15 | Championx Usa Inc. | Slow-release scale inhibiting compositions |
US11142680B2 (en) | 2016-12-23 | 2021-10-12 | Championx Usa Inc. | Controlled release solid scale inhibitors |
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