Corrosion inhibition package

Abstract

A corrosion inhibition package for use with an aqueous acid composition, said package comprising: a terpene; a cinnamaldehyde or a derivative thereof; at least one amphoteric surfactant; and a solvent. Also disclosed are compositions comprising said corrosion inhibitor package. Preferably, the corrosion inhibition package meets the environmental requirements for classification as yellow according to the Norwegian North Sea offshore drilling regulatory requirements.

Claims

1. A corrosion inhibition package for use with an aqueous acid composition, said corrosion inhibition package comprising a corrosion inhibitor component, which said corrosion inhibitor component comprises a terpene; a cinnamaldehyde or a derivative thereof; at least one amphoteric surfactant, wherein the at least one amphoteric surfactant is selected from the group consisting of an amido betaine surfactant, an amido sultaine surfactant, and combinations thereof; an anionic surfactant which is a dicarboxylic surfactant; and a solvent, and wherein the terpene is selected from the group consisting of citral, carvone, ionone, ocimene, cymene, and combinations thereof, the terpene is present in an amount ranging from 5% to 30% by volume of the total volume of the corrosion inhibition package, the cinnamaldehyde or derivative thereof is present in an amount ranging from 5% to 30% by volume of the total volume of the corrosion inhibition package, and the at least one amphoteric surfactant is present in an amount ranging from 2% to 20% by volume of the total volume of the corrosion inhibition package.

2. The corrosion inhibition package as claimed in claim 1, wherein the corrosion inhibition package is a non-emulsion corrosion inhibitor package and the corrosion inhibitor component is a water-soluble corrosion inhibitor component.

3. The corrosion inhibition package as claimed in claim 1, wherein the terpene is selected from the group consisting of citral and ocimene, the amphoteric surfactant is an amido betaine with a hydrophobic tail ranging from C8 to C16; and the dicarboxylic surfactant is a dicarboxylic surfactant with a hydrophobic tail ranging from C8 to C16.

4. The corrosion inhibition package as claimed in claim 1, wherein the solvent is present in an amount ranging from 25% to 80% by volume of the total volume of the corrosion inhibition package.

5. The corrosion inhibition package as claimed in claim 1, wherein the amphoteric surfactant is an amido betaine with a hydrophobic tail ranging from C8 to C16.

6. The corrosion inhibition package as claimed in claim 5, wherein the amphoteric surfactant is cocamidopropyl betaine.

7. The corrosion inhibition package as claimed in claim 1, wherein the dicarboxylic surfactant is a dicarboxylic surfactant with a hydrophobic tail ranging from C8 to C16.

8. The corrosion inhibition package as claimed in claim 7, wherein the dicarboxylic surfactant is sodium lauriminodipropionate.

9. The corrosion inhibition package as claimed in claim 1, wherein the solvent is selected from the group consisting of: isopropanol; methanol; ethanol; 2-butoxyethanol; diethylene glycol; a short chain ethoxylate; and combinations thereof.

10. The corrosion inhibition package as claimed in claim 1, further comprising a corrosion inhibitor intensifier, wherein the corrosion inhibitor intensifier is selected from the group consisting of metal iodide or iodate, aluminum chloride, calcium chloride, bismuth chloride and magnesium chloride, and combinations thereof.

11. The corrosion inhibition package as claimed in claim 10, wherein the corrosion inhibitor intensifier is a metal iodide or iodate selected from the group consisting of potassium iodide, sodium iodide, cuprous iodide and lithium iodide and combinations thereof.

12. A corrosion inhibition package for use with an aqueous acid composition, said corrosion inhibition package comprising a corrosion inhibitor component, wherein said corrosion inhibitor component consists of a terpene selected from the group consisting of citral, ocimene, and combinations thereof; a cinnamaldehyde or a derivative thereof; at least one amphoteric surfactant which is an amido betaine surfactant; an anionic surfactant which is a dicarboxylic surfactant; and a solvent; wherein the corrosion inhibitor component is water soluble and the volume % of the corrosion package in the aqueous acid composition ranges from 0.1 to 10%.

13. An aqueous synthetic or modified acid composition comprising the corrosion inhibition package of claim 1, and an acidic solution selected from the group consisting of: HCl; Lysine-HCl; Urea-HCl; hydrofluoric acid; sulfuric acid; methanesulfonic acid; methanesulfonic acid-Urea; phosphoric acid; phosphoric acid-urea; p-toluene sulfonic acid; and monoethylamine-HCl, wherein the volume % of the corrosion package in the acidic composition ranges from 0.1 to 10%.

14. The aqueous synthetic or modified acid composition according to claim 13, further comprising a corrosion intensifier, wherein the corrosion intensifier is present in a weight/volume percentage ranging from 0.1 to 1.5% of the total volume of the aqueous acidic composition.

15. The aqueous synthetic or modified acid composition according to claim 14, wherein the corrosion inhibitor intensifier is potassium iodide in an amount ranging from 0.25 to 1.25% vol./vol. of the acidic composition.

16. The aqueous synthetic or modified acid composition according to claim 15, with an acid corrosion number less than 0.02 lb/ft.sup.2.

17. A method of using a corrosion inhibitor package with an acidic composition in the oil industry, said method comprising the step of providing the corrosion inhibitor package according claim 1 with the acidic composition, wherein the acidic composition comprises an acid selected from the group consisting of: a mineral acid, an organic acid, a modified acid, a complexed acid and a synthetic acid.

18. A method of using an aqueous acidic composition in the oil industry, said method comprising the steps of: preparing the corrosion inhibition package according to claim 1; providing an aqueous acid solution; mixing the package into the aqueous acidic solution; applying the resulting composition to a metal surface; allowing the acid composition a sufficient period of time to act upon said surface; and optionally, removing the acid composition when the exposure time has been determined to be sufficient for the operation to be complete or sufficiently complete.

19. The method according to claim 17 to perform an activity in the oil industry where the activity is selected from the group consisting of: stimulating formations; assisting in reducing breakdown pressures during downhole pumping operations; treating wellbore filter cake post drilling operations; assisting in freeing stuck pipe; descaling pipelines and/or production wells; increasing injectivity of injection wells; lowering the pH of a fluid; fracturing wells; performing matrix stimulations; conducting annular and bullhead squeezes & soaks; pickling tubing, pipe and/or coiled tubing; increasing effective permeability of formations; reducing or removing wellbore damage; cleaning perforations; solubilizing limestone, dolomite, and calcite; and scale removal from a surface selected from the group consisting of: equipment, wells and related equipment and facilities.

Description

DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS

(1) The description that follows, and the embodiments described therein, is provided by way of illustration of an example, or examples, of particular embodiments of the principles of the present invention. These examples are provided for the purposes of explanation, and not limitation, of those principles and of the invention.

(2) According to an aspect of the invention, there is provided a corrosion inhibition package for use with an acidic composition which will be placed in contact with a metallic surface, said corrosion inhibition package comprising: a terpene; cinnamaldehyde or a derivative thereof; at least one amphoteric surfactant; and a solvent.

(3) Preferably, the corrosion inhibition package is used with an acidic composition such as a synthetic acid composition comprising: lysine & hydrogen chloride in a molar ratio of not less than 1:12; preferably in a molar ratio not less than 1:8, more preferably in a molar ratio of not less than 1:5, even more preferably in a molar ratio of not less than 1:3 and even more preferably in a molar ratio of not less than 1:2.5.

(4) According to another preferred embodiment, the corrosion inhibition package is used with an acidic composition such as a synthetic or modified acid composition comprising: urea and hydrogen chloride in a molar ratio of not less than 0.1:1; more preferably in the urea and hydrogen chloride are present in a molar ratio of not less than 0.5:1; yet more preferably in the urea and hydrogen chloride are present in a molar ratio of not less than 0.7:1, and even more preferably in the urea and hydrogen chloride are present in a molar ratio of not less than 1:1.

(5) According to yet another preferred embodiment of the present invention, a corrosion inhibition package comprising a terpene; cinnamaldehyde or a derivative thereof; at least one amphoteric surfactant; and a solvent, can be used with neat HCl. The % volume of the corrosion inhibition package will be determined by the temperature at which the composition will be exposed when in use, as well as the type of metal, the concentration of the HCl and duration of time of exposure. Preferably, the corrosion inhibition package should be present in a concentration ranging from 0.1% to 5 vol % of the volume of the composition.

(6) Preferably, when the synthetic or modified acid composition comprises lysine and hydrogen chloride, the molar ratio of lysine to HCl can range from 1:2 to 1:12; preferably in a molar ratio ranging from 1:2.5 to 1:8, more preferably in a molar ratio ranging from 1:3 to 1:6, even more preferably in a molar ratio ranging from 1:3 to 1:5.

(7) The terpenes considered by the inventors to achieve desirable corrosion inhibition results comprise: monoterpenes (acyclic); monocyclic terpenes; and beta-Ionone. Exemplary but non-limiting compounds of some of the previously listed terpene sub-classes comprise: for monoterpenes: citral (mixture of geranial and neral); citronellal; geraniol; and ocimene; for monocyclic terpenes: alpha-terpinene; carvone; p-cymene. More preferably, the terpenes are selected from the group consisting of: citral; ionone; ocimene; and cymene. Most preferred is citral.

(8) According to a preferred embodiment of the present invention, the corrosion inhibition package comprises a surfactant which is environmentally friendly. More preferably, the surfactant is capable of withstanding exposure to temperatures of up to least 130° C. for a period of 2 to 6 hours in a closed environment without undergoing degradation.

(9) Preferably, the at least one amphoteric surfactant is selected from the group consisting of: a sultaine surfactant; a betaine surfactant; and combinations thereof. More preferably, the sultaine surfactant and betaine surfactant are selected from the group consisting of: an amido betaine surfactant; an amido sultaine surfactant; and combinations thereof. Yet even more preferably, the amido betaine surfactant and is selected from the group consisting of: an amido betaine comprising a hydrophobic tail from C8 to C16. Most preferably, the amido betaine comprising a hydrophobic tail from C8 to C16 is cocamidobetaine.

(10) Preferably, the cinnamaldehyde derivative are selected from the group consisting of: dicinnamaldehyde p-hydroxycinnamaldehyde; p-methylcinnamaldehyde; p-ethylcinnamaldehyde; p-methoxycinnamaldehyde; p-dimethylaminocinnamaldehyde; p-diethylaminocinnamaldehyde; p-nitrocinnamaldehyde; o-nitrocinnamaldehyde; 4-(3-propenal)cinnamaldehyde; p-sodium sulfocinnamaldehyde p-trimethylammoniumcinnamaldehyde sulfate; p-trimethylammoniumcinnamaldehyde o-methyl sulfate; p-thiocyanocinnamaldehyde; p-(S-acetyl)thiocinnamaldehyde; p-(S—N,N-dimethylcarbamoylthio)cinnamaldehyde; p-chlorocinnamaldehyde; a-methylcinnamaldehyde; β-methylcinnamaldehyde; a-chlorocinnamaldehyde a-bromocinnamaldehyde; a-butylcinnamaldehyde; a-amylcinnamaldehyde; a-hexylcinnamaldehyde; α-bromo-p-cyanocinnamaldehyde; α-ethyl-p-methylcinnamaldehyde and p-methyl-a-pentylcinnamaldehyde.

(11) Preferably also, the corrosion inhibition package further comprises an anionic surfactant. Preferably, the anionic surfactant is a carboxylic surfactant. More preferably, the carboxylic surfactant is a dicarboxylic surfactant. Even more preferably, the dicarboxylic surfactant comprises a hydrophobic tail ranging from C8 to C16. Most preferably, the dicarboxylic surfactant is sodium lauriminodipropionate

(12) A preferred embodiment can refer to a corrosion inhibition package comprising cocamidopropyl betaine and ß-Alanine, N-(2-carboxyethyl)-N-dodecyl-, sodium salt (1:1).

(13) According to a preferred embodiment of the present invention, when preparing an acidic composition comprising a corrosion inhibition package, metal iodides or iodates such as potassium iodide, sodium iodide, cuprous iodide and lithium iodide can be added as corrosion inhibitor intensifier. The iodide or iodate is preferably present in a weight/volume percentage ranging from 0.1 to 1.5%, more preferably from 0.25 to 1.25%, yet even more preferably 1% by weight/volume of the acidic composition. Most preferably, the iodide used is potassium iodide. According to a preferred embodiment, chlorides such as aluminum chloride, calcium chloride, bismuth chloride and magnesium chloride can be used instead of metal iodides or iodates as intensifiers.

(14) According to a preferred embodiment of the present invention, the corrosion package comprises: cocamidopropyl betaine in an amount of approximately 5% by volume of the total volume of the package; Citral in an amount of approximately 10% by volume of the total volume of the package; cinnamaldehyde in an amount of approximately 10% by volume of the total volume of the package; and methanol in an amount of approximately 75% by volume of the total volume of the package.

(15) Also, preferably, the corrosion inhibition package is used with an acidic composition such as a modified acid composition comprising: a strong acid and an alkanolamine in a molar ratio of not more than 15:1; preferably in a molar ratio not more than 10:1, more preferably in a molar ratio of not more than 8:1; even more preferably in a molar ratio of not more than 5:1; yet even more preferably in a molar ratio of not more than 3.5:1; and yet even more preferably in a molar ratio of not less than 2.5:1.

(16) In that respect, the composition comprises an alkanolamine and a strong acid, such as HCl, nitric acid, sulfuric acid, sulfonic acid. The alkanolamine according to the present invention contains at least one amino group, —NH 2, and one alcohol group, —OH. Preferred alkanolamines include, but are not limited to, monoethanolamine, diethanolamine and triethanolamine. More preferred are monoethanolamine, diethanolamine. Most preferred is monoethanolamine.

(17) According to a preferred method of use, the corrosion inhibitor package is mixed with an acid prior to its transport to a job site. Alternatively, a corrosion inhibitor package according to the present invention can be mixed with the acid prior to its use while using proper mixing equipment and mixing the combined composition thoroughly to ensure homogenous mixing.

Example 1—Process to Prepare an Acidic Composition Comprising a Corrosion Inhibition Package According to a Preferred Embodiment of the Invention

(18) The corrosion inhibition package is prepared by dispersing a terpene component in a solvent, in this case methanol, and at least one surfactant. Afterwards, the corrosion inhibition package thus prepared is mixed with an acidic composition. Applying this procedure, allows for the formation of a surfactant complex as described below.

(19) According to a preferred embodiment of the present invention, since the corrosion inhibition package is intended for use at high temperatures, the combination of a betaine and a carboxylic surfactant is desirable. The combination of a carboxylic surfactant and a betaine is known to form a 1:1 or 1:2 complex, which also has a high molecular weight. Therefore, it is important to disperse the terpene component into isopropanol. Otherwise, the resulting acidic composition may not meet the class 1 fluid (transparent, no phase separation).

(20) To prepare an aqueous acidic composition of a modified acid, lysine mono-hydrochloride is used as starting reagent. To obtain a 1:2 molar ratio of lysine to HCl, 370 ml of 50 wt % lysine-HCl solution and 200 ml HCl aq. 36% (22 Baume) are combined. The corrosion inhibition package and potassium iodide are added at this point. Circulation is maintained until all products have been solubilized. Additional products can now be added as required.

(21) The resulting composition of Example 1 is an amber-colored liquid with a fermentation-like odour having an expected shelf-life of greater than a year. It has a freezing point temperature of approximately minus 45° C. and a boiling point temperature of approximately 100° C. It has a specific gravity of 1.15±0.02. It is completely soluble in water and its pH is less than 1. The composition is biodegradable and is classified as a mild irritant according to the classifications for skin tests. The composition is substantially low fuming. Toxicity testing was calculated using surrogate information and the LD.sub.50 was determined to be greater than 2000 mg/kg.

(22) With respect to the corrosion impact of the acidic composition on typical oilfield grade steel alloys, it was established that it was clearly well below the acceptable corrosion limits set by industry making it highly desirable as corrosion is the main challenge during acid applications causing substantial maintenance and workover costs over time.

(23) Corrosion Inhibition Package Formulations

(24) Various types of steel alloy coupons were subjected to corrosion testing in the presence of conventional, synthetic and modified acid compositions using corrosion inhibitor components according to preferred embodiments of the present invention at various temperatures. The results of the corrosion tests are reported in Tables 3 through 31. Coupons of various grades of steel alloys (indicated in each table) were exposed to the various listed compositions for various periods of time at varying temperatures. When the fluid system is diluted, it is so indicated in the table or title. For example, 50% indicates that the fluid system was diluted to half strength with tap water. Also, 50% seawater indicates that the fluid system was diluted to half strength with seawater (or an equivalent brine solution).

(25) According to preferred embodiment of the present invention, citral can be present in a concentration ranging from 5 to 30 vol % of the total volume of the corrosion inhibition package; cinnamaldehyde can be present in a concentration ranging from 5 to 30 vol %; and cocamido betaine can be present in a concentration ranging from 2.5 to 15 vol %. Depending on various factors, such as temperature, acid, metal, etc. preferred corrosion inhibitor package loadings within the acid compositions can range between 0.1 to 7.5% vol/vol. More preferably, between 0.1 and 5% vol/vol. Biodegradation, toxicity and bioaccumulation testing carried out has indicated that most of the compositions listed below in Tables 1 and 2 have been identified as satisfactorily meeting the requirements for listing under a classification of Yellow for offshore use in the North Sea (Norway).

(26) TABLE-US-00001 TABLE 1 List of Component and Content in Corrosion Inhibition Packages FCI-XV to FCI-XP (All figures are in vol %) FCI- FCI- FCI- FCI- FCI- FCI- FCI- Compound XV XT XS XR XQ XO XP Cocamidopropyl 10 10 10 10 5 5 10 betaine ß-Alanine, 10 N-(2-carboxyethyl)-N- dodecyl-, sodium salt (1:1) Citral 10 20 25 25 25 25 25 Cinnamaldehyde 25 10 10 10 Carvone 10 Methanol 80 70 40 55 60 60 45 Total vol. % 100 100 100 100 100 100 100

(27) TABLE-US-00002 TABLE 2 List of Component and Content in Corrosion Inhibition Packages FCI-XN to FCI-XK (All figures are in vol %) FCI- FCI- FCI- FCI- FCI- FCI- Compound XN XM XL XI XJ XK Cocamidopropyl betaine 10 5 5 10 5 5 ß.-Alanine, N-(2- 10 5 10 5 carboxyethyl)-N-dodecyl-, sodium salt (1:1) Citral 10 10 10 15 15 15 Cinnamaldehyde 10 10 10 10 10 10 Carvone Methanol 60 75 70 55 70 65 Total vol. % 100 100 100 100 100 100
Corrosion Testing

(28) The following corrosion testing outlined in the tables below for a number of different corrosion inhibition packages according to the present invention in the presence of a synthetic or modified acid composition was carried out diluted with saline water (in most cases) at various temperatures for various durations of exposure. Depending on the intended use/application of an acidic fluid composition comprising a corrosion inhibitor package according to the present invention, a desirable result would be one where the lb/ft.sup.2 corrosion number is at or below 0.05. A more desirable would be one where the corrosion (in lb/ft.sup.2) is at or below 0.02. Generally, seawater has the deleterious effect of potentiating corrosion, consequently corrosion inhibition packages which follow the guidelines or regulations for offshore oil production are highly desirable for operators. Where applicable the fluids (acid compositions) were diluted as indicated.

(29) The following abbreviations are used in the corrosion results tables: CI-1A—10% aqueous KI solution; ZA—Cinnamaldehyde; and CA—Citral.

(30) TABLE-US-00003 TABLE #3 Corrosion test results from tests conducted at 90° C. for a period ranging for 6 hours with a coupon density of 7.86 g/cc having a surface area of 41.4 cm.sup.2 (coupons used were 1018 steel) Corrosion Wt loss Fluid Dilution Package (g) Mils/yr mm/year lb/ft2 1.2:1 50% dilution in 1% ZA 0.168 296.053 7.52 0.008 HCl-Urea seawater 1% CI-1A 1.2:1 50% dilution in 1% FCI-XT 0.54 954.5765 24.246 0.027 HCl-Urea seawater 1% CI-1A 1.2:1 50% dilution in 1.5% FCI-XT 0.439 775.1076 19.688 0.022 HCl-Urea seawater 1% CI-1A 1.2:1 50% dilution in 1% FCI-XS 0.18 318.6632 8.094 0.009 HCl-Urea seawater 1% CI-1A 1.2:1 50% dilution in 1% FCI-XS 0.238 420.7626 10.687 0.012 HCl-Urea seawater 0.5% CI-1A 1.2:1 50% dilution in 1.5% FCI-XS 0.151 266.9069 6.779 0.007 HCl-Urea seawater 1% CI-1A 1.2:1 50% dilution in 1.5% FCI-XS 0.185 327.4953 8.318 0.009 HCl-Urea seawater 0.5% CI-1A 1.2:1 50% dilution in 2.5% FCI-XS 0.124 218.6835 5.555 0.006 HCl-Urea seawater 1% CI-1A 1.2:1 50% dilution in 2.5% FCI-XS 0.149 263.904 6.703 0.007 HCl-Urea seawater 0.5% CI-1A 1.2:1 50% dilution in 1% FCI-XR 0.235 415.2867 10.548 0.012 HCl-Urea seawater 1% CI-1A 1.2:1 50% dilution in 1.5% FCI-XR 0.153 270.6164 6.874 0.008 HCl-Urea seawater 1% CI-1A 1.2:1 50% dilution in 1% FCI-XQ 0.274 484.3539 12.303 0.014 HCl-Urea seawater 1% CI-1A 1.2:1 50% dilution in 1% FCI-XQ 0.341 602.5278 15.304 0.017 HCl-Urea seawater 0.5% CI-1A 1.2:1 Diluted in 50% 1.5% FCI-XQ 0.18 318.1333 8.081 0.009 HCl-Urea seawater 1% CI-1A 1.2:1 Diluted in 50% 1.5% FCI-XQ 0.255 450.0853 11.432 0.013 seawater 0.5% CI-1A 1.2:1 Diluted in 50% 1% FCI-XR 0.312 551.3015 14.003 0.015 seawater 0.5% CI-1A 1.2:1 Diluted in 50% 1.5% FCI-XR 0.182 321.6661 8.17 0.009 seawater 1% CI-1A 1.2:1 Diluted in 50% 1.5% FCI-XR 0.213 375.7188 9.543 0.011 HCl-Urea seawater 0.5% CI-1A Where the ratios are molar ratios and where CI-1A indicates potassium iodide present as intensifier . . .

(31) TABLE-US-00004 TABLE #4 Corrosion test results from tests conducted at 110° C. for a period ranging for 6 hours with a coupon density of 7.86 g/cc having a surface area of 41.4 cm.sup.2 (coupons used were 1018 steel) Corrosion Wt loss Fluid Package (g) Mils/yr mm/year lb/ft2 21% MSA 1.5% FCI-XQ 0.125 220.8032 5.608 0.006 (diluted in 1% CI-1A seawater) 21% MSA 1.5% FCI-XR 0.1 176.4659 4.482 0.005 (diluted in 1% CI-1A seawater) 21% MSA 1.5% FCI-XS 0.081 143.6104 3.648 0.004 (diluted in 1% CI-1A seawater) 21% MSA 1.5% FCI-XT 1.073 1895.022 48.134 0.053 (diluted in 1% CI-1A seawater) 21% MSA 1.5% FCI-XP 0.048 85.49501 2.172 0.002 (diluted in 1% CI-1A seawater) wherein the 21% MSA solution diluted in seawater is prepare by adding 1 part volume of 42% methanesulfonic acid to 1 part volume seawater

(32) TABLE-US-00005 TABLE #5 Corrosion test results from tests conducted at 90° C. for a period ranging for 6 hours with a coupon density of 7.86 g/cc having a surface area of 41.4 cm.sup.2 (coupons used were 1018 steel) Corrosion Wt loss Fluid Dilution Package (g) Mils/yr mm/year lb/ft2 1.2:1 50% dilution in 1% FCI-XS 0.171 301.3522 7.654 0.008 HCl-Urea seawater 1% CI-1A 1.2:1 50% dilution in 1% FCI-XS 0.226 399.9188 10.158 0.011 HCl-Urea seawater 0.5% CI-1A 1.2:1 50% dilution in 1.5% FCI-XS 0.127 224.6894 5.707 0.006 HCl-Urea seawater 1% CI-1A 1.2:1 50% dilution in 1.5% FCI-XS 0.147 260.3712 6.613 0.007 HCl-Urea seawater 0.5% CI-1A

(33) TABLE-US-00006 TABLE #6 Corrosion test results from tests conducted at 130° C. for a period ranging for 6 hours with a coupon density of 7.86 g/cc having a surface area of 41.4 cm.sup.2 (coupons used were 1018 steel) Corrosion Wt loss Fluid Package (g) Mils/yr mm/year lb/ft2 21% MSA 1.5% FCI-XQ 2.249 3971.808 100.884 0.111 (diluted in 1% CI-1A seawater) 21% MSA 1.5% FCI-XR 1.763 3114.032 79.096 0.087 (diluted in 1% CI-1A seawater) 21% MSA 1.5% FCI-XS 0.237 418.8195 10.638 0.012 (diluted in 1% CI-1A seawater) 21% MSA 1.5% FCI-XT 2.849 5032.37 127.822 0.141 (diluted in 1% CI-1A seawater) 21% MSA 1.5% FCI-XP 0.114 201.9025 5.128 0.006 (diluted in 1% CI-1A seawater)

(34) TABLE-US-00007 TABLE #7 Corrosion test results from tests conducted at 90° C. for a period ranging for 4 or 6 hours with a coupon density of 7.86 g/cc having a surface area of 26.01 cm.sup.2 (coupons used were CR-13-110 polished) Corrosion Wt loss Time Fluid Dilution Package (g) (hours) Mils/yr mm/year lb/ft2 HCR-2000N 50% dilution in 5% FCI-XR 0.66 4 2785.604 70.754 0.044 seawater 5% CI-1A HCR-2000N 50% dilution in 5% FCI-XP 0.459 4 1934.108 49.126 0.03 seawater 5% CI-1A

(35) TABLE-US-00008 TABLE #8 Corrosion test results from tests conducted at 70° C. for a period ranging for 6 hours with a coupon density of 7.86 g/cc having a surface area of 41.4 cm.sup.2 (coupons used were 1018 steel) Corrosion Wt loss Fluid Dilution Package (g) Mils/yr mm/year lb/ft2 1.2:1 50% dilution in 1% FCI-XQ 0.076 133.3651 3.387 0.004 HCl-Urea seawater 1% CI-1A 1.2:1 50% dilution in 1% FCI-XQ 0.09 158.2717 4.02 0.004 HCl-Urea seawater 0.5% CI-1A 1.2:1 50% dilution in 1.5% FCI-XQ 0.076 133.5418 3.392 0.004 HCl-Urea seawater 1% CI-1A 1.2:1 50% dilution in 1.5% FCI-XQ 0.087 153.679 3.903 0.004 HCl-Urea seawater 0.5% CI-1A 1.2:1 50% dilution in 1% FCI-XR 0.081 142.3739 3.616 0.004 HCl-Urea seawater 1% CI-1A 1.2:1 50% dilution in 1% FCI-XR 0.097 171.1667 4.348 0.005 HCl-Urea seawater 0.5% CI-1A 1.2:1 50% dilution in 1.5% FCI-XR 0.076 133.5418 3.392 0.004 HCl-Urea seawater 1% CI-1A 1.2:1 50% dilution in 1.5% FCI-XR 0.091 160.7447 4.083 0.005 HCl-Urea seawater 0.5% CI-1A 1.2:1 50% dilution in 1% FCI-XS 0.077 136.0148 3.455 0.004 HCl-Urea seawater 1% CI-1A 1.2:1 50% dilution in 1% FCI-XS 0.097 170.8134 4.339 0.005 HCl-Urea seawater 0.5% CI-1A 1.2:1 50% dilution in 1.5% FCI-XS 0.065 114.9943 2.921 0.003 HCl-Urea seawater 1% CI-1A 1.2:1 50% dilution in 1.5% FCI-XS 0.07 124.0031 3.15 0.003 HCl-Urea seawater 0.5% CI-1A

(36) TABLE-US-00009 TABLE #9 Corrosion test results from tests conducted at 110° C. for a period ranging for 6 hours with a coupon density of 7.86 g/cc having a surface area of 41.4 cm.sup.2 (coupons used were 1018 steel) Corrosion Wt loss Fluid Dilution Package (g) Mils/yr mm/year lb/ft2 4.5:1 50% dilution in 1.5% FCI-XQ 0.463 817.5018 20.765 0.023 HCl-Lysine seawater 1% CI-1A 4.5:1 50% dilution in 1.5% FCI-XR 0.176 311.4209 7.91 0.009 HCl-Lysine seawater 1% CI-1A 4.5:1 50% dilution in 1.5% FCI-XS 0.157 276.6223 7.026 0.008 HCl-Lysine seawater 1% CI-1A 4.5:1 50% dilution in 1.5% FCI-XP 0.238 421.1159 10.696 0.012 HCl-Lysine seawater 1% CI-1A 4.5:1 50% dilution in 1.5% FCI-XT 1.12 1978.927 50.265 0.055 HCl-Lysine seawater 1% CI-1A

(37) TABLE-US-00010 TABLE #10 Corrosion test results from tests conducted at 90° C. for a period ranging for 6 hours with a coupon density of 7.86 g/cc having a surface area of 28.922 cm.sup.2 (coupons used were J55 steel) Corrosion Wt loss Fluid Dilution Package (g) Mils/yr mm/year lb/ft2 observations 7.5% HCl None None 1.404 3550.3032 90.178 0.100 15% HCl None None 2.175 5500.3023 139.708 0.154 1.2:1 50% dilution in 1.5% FCI-XP 0.119 300.3889 7.63 0.008 no pits HCl-Urea seawater 1% CI-1A 1.2:1 50% dilution in 1.5% FCI-XQ 0.218 551.4715 14.007 0.015 no pits HCl-Urea seawater 1% CI-1A 1.2:1 50% dilution in 1.5% FCI-XR 0.216 546.6673 13.885 0.015 no pits HCl-Urea seawater 1% CI-1A 1.2:1 50% dilution in 1.5% FCI-XS 0.186 470.8115 11.959 0.013 no pits HCl-Urea seawater 1% CI-1A

(38) TABLE-US-00011 TABLE #11 Corrosion test results from tests conducted at 90° C. for a period ranging for 6 hours with a coupon density of 7.86 g/cc having a surface area of 30.199 cm.sup.2 (coupons used were N80 steel) Corrosion Wt loss Fluid Dilution Package (g) Mils/yr mm/year lb/ft2 observations HCl-Urea none none 0.117 304.9971 7.747 0.009 (control) HCl-Urea 50% dilution in none 0.370 963.1762 24.465 0.027 seawater 1.2:1 50% dilution in 1.5% FCI-XP 0.128 310.2075 7.879 0.009 few pits on HCl-Urea seawater 1% CI-1A side/back 1.2:1 50% dilution in 1.5% FCI-XQ 0.278 672.4795 17.081 0.019 no pits HCl-Urea seawater 1% CI-1A 1.2:1 50% dilution in 1.5% FCI-XR 0.247 598.3784 15.199 0.017 no pits HCl-Urea seawater 1% CI-1A 1.2:1 50% dilution in 1.5% FCI-XS 0.206 500.0613 12.702 0.014 no pits HCl-Urea seawater 1% CI-1A

(39) TABLE-US-00012 TABLE #12 Corrosion test results from tests conducted at 90° C. for a period ranging for 6 hours with a coupon density of 7.86 g/cc having a surface area of 30.199 cm.sup.2 (coupons used were L80 steel) Corrosion Wt loss Fluid Dilution Package (g) Mils/yr mm/year lb/ft2 observations 1.2:1 50% dilution in 1.5% FCI-XP 0.153 369.779 9.392 0.01 few pits on HCl-Urea seawater 1% CI-1A side/back 1.2:1 50% dilution in 1.5% FCI-XQ 0.289 698.875 17.751 0.02 no pits HCl-Urea seawater 1% CI-1A 1.2:1 50% dilution in 1.5% FCI-XR 0.296 716.0684 18.188 0.02 no pits HCl-Urea seawater 1% CI-1A 1.2:1 50% dilution in 1.5% FCI-XS 0.232 562.5387 14.288 0.016 no pits HCl-Urea seawater 1% CI-1A

(40) TABLE-US-00013 TABLE #13 Corrosion test results from tests conducted at 90° C. for a period ranging for 6 hours with a coupon density of 7.86 g/cc having a surface area of 28.922 cm.sup.2 (coupons used were P110 steel) Corrosion Wt loss Fluid Dilution Package (g) Mils/yr mm/year lb/ft2 observations 1.2:1 50% dilution in 1.5% FCI-XP 1.575 3983.187 101.173 0.078 no pits HCl-Urea seawater 1% CI-1A 1.2:1 50% dilution in 1.5% FCI-XQ 0.645 1630.141 41.406 0.046 Yes, some HCl-Urea seawater 1% CI-1A pits on sides 1.2:1 50% dilution in 1.5% FCI-XR 0.77 1945.954 49.427 0.055 Yes, some HCl-Urea seawater 1% CI-1A pits on sides 1.2:1 50% dilution in 1.5% FCI-XS 0.387 978.5395 24.855 0.027 no pits HCl-Urea seawater 1% CI-1A

(41) TABLE-US-00014 TABLE #14 Corrosion test results from tests conducted at 130° C. for a period ranging for 6 hours with a coupon density of 7.86 g/cc having a surface area of 28.922 cm.sup.2 (coupons used were 1018 steel) Corrosion Wt loss Surface Fluid Dilution Package (g) area Mils/yr mm/year lb/ft2 4.5:1 50% dilution in 1.5% FCI-XQ 1.399 28.922 3537.913 89.863 0.099 HCl-Lysine seawater 1% CI-1A 4.5:1 50% dilution in 1.5% FCI-XR 1.114 41.4 1966.915 49.96 0.055 HCl-Lysine seawater 1% CI-1A 4.5:1 50% dilution in 1.5% FCI-XS 0.336 41.4 592.8125 15.057 0.017 HCl-Lysine seawater 1% CI-1A 4.5:1 50% dilution in 1.5% FCI-XT 3.839 41.4 6780.955 172.236 0.19 HCl-Lysine seawater 1% CI-1A 4.5:1 50% dilution in 1.5% FCI-XP 0.315 41.4 556.4241 14.133 0.016 HCl-Lysine seawater 1% CI-1A

(42) TABLE-US-00015 TABLE #15 Corrosion test results from tests conducted at 90° C. for a period ranging for 6 hours with a coupon density of 7.86 g/cc having a surface area of 41.4 cm.sup.2 (coupons used were 1018 steel) Corrosion Wt loss Fluid Package (g) Mils/yr mm/year lb/ft2 15% HCl 1.5% FCI-XP 0.075 132.8352 3.374 0.004 1% CI-1A 15% HCl 2.5% FCI-XP 0.068 119.587 3.038 0.003 1% CI-1A 15% HCl 1.5% FCI-XQ 1.121 1980.693 50.31 0.055 1% CI-1A 15% HCl 2.5% FCI-XQ 0.793 1400.069 35.562 0.039 1% CI-1A 15% HCl 1.5% FCI-XR 0.176 310.8909 7.897 0.009 1% CI-1A 15% HCl 2.5% FCI-XR 0.215 380.4881 9.664 0.011 1% CI-1A 15% HCl 1.5% FCI-XS 0.2 353.2851 8.973 0.01 1% CI-1A 15% HCl 2.5% FCI-XS 0.228 402.2151 10.216 0.011 1% CI-1A

(43) TABLE-US-00016 TABLE #16 Corrosion test results from tests conducted at 90° C. for a period ranging for 6 hours with a coupon density of 7.86 g/cc having a surface area of 30.199 cm.sup.2 (coupons used were L80 steel) Corrosion Wt loss Fluid Dilution Package (g) Mils/yr mm/year lb/ft2 Observations 1.2:1 50% dilution 1.5% FCI-XP 0.18 435.6466 11.065 0.012 few pits on HCl-Urea in seawater 0.5% CI-1A side/back 1.2:1 50% dilution 1.5% FCI-XQ 0.305 738.8314 18.766 0.021 no pits HCl-Urea in seawater 0.5% CI-1A 1.2:1 50% dilution 1.5% FCI-XR 0.305 738.8314 18.766 0.021 no pits HCl-Urea in seawater 0.5% CI-1A 1.2:1 50% dilution 1.5% FCI-XS 0.317 766.4377 19.468 0.021 no pits HCl-Urea in seawater 0.5% CI-1A

(44) TABLE-US-00017 TABLE #17 Corrosion test results from tests conducted at 90° C. for a period ranging for 6 hours with a coupon density of 7.86 g/cc having a surface area of 28.922 cm.sup.2 (coupons used were P110 steel) Corrosion Wt loss Fluid Dilution Package (g) Mils/yr mm/year lb/ft2 Observations 1.2:1 50% dilution 1.5% FCI-XP 0.388 981.3209 24.926 0.026 few pits on HCl-Urea in seawater 0.5% CI-1A side/back 1.2:1 50% dilution 1.5% FCI-XQ 0.589 1489.555 37.835 0.042 few pits on HCl-Urea in seawater 0.5% CI-1A side/back 1.2:1 50% dilution 1.5% FCI-XR 0.662 1674.896 42.542 0.047 few pits on HCl-Urea in seawater 0.5% CI-1A side/back 1.2:1 50% dilution 1.5% FCI-XS 0.376 951.2314 24.161 0.027 few pits on HCl-Urea in seawater 0.5% CI-1A side/back

(45) TABLE-US-00018 TABLE #18 Corrosion test results from tests conducted at 90° C. for a period ranging for 6 hours with a coupon density of 7.86 g/cc having a surface area of 41.4 cm.sup.2 (coupons used were 1018 steel) Corrosion Wt loss Fluid Dilution Package (g) Mils/yr mm/year lb/ft2 15% HCl 50% dilution 1% FCI-XP 0.135 239.3507 6.08 0.007 in seawater 1% CI-1A 15% HCl 50% dilution 1% FCI-XP 0.206 364.0603 9.247 0.01 in seawater 0.5% CI-1A 15% HCl 50% dilution 0.75% FCI-XP 0.094 166.7506 4.235 0.005 in seawater 1% CI-1A 15% HCl 50% dilution 0.75% FCI-XP 0.242 427.1217 10.849 0.012 in seawater 0.5% CI-1A 15% HCl 50% dilution 1% FCI-XQ 1.173 2072.901 52.652 0.058 in seawater 0.5% CI-1A 15% HCl 50% dilution 1% FCI-XR 1.204 2126.07 54.002 0.06 in seawater 0.5% CI-1A 15% HCl 50% dilution 0.75% FCI-XQ 1.022 1805.11 45.85 0.051 in seawater 0.5% CI-1A 15% HCl 50% dilution 0.75% FCI-XR 0.801 1415.084 35.943 0.04 in seawater 0.5% CI-1A

(46) TABLE-US-00019 TABLE #19 Corrosion test results from tests conducted at 90° C. for a period ranging for 6 hours with a coupon density of 7.86 g/cc having a surface area of 41.4 cm.sup.2 (coupons used were 4140 steel) Corrosion Wt loss Fluid Dilution Package (g) Mils/yr mm/year lb/ft2 15% HCl 50% dilution 1% FCI-XQ 2.553 4510.215 114.559 0.126 in seawater 0.5% CI-1A 15% HCl 50% dilution 1% FCI-XR 1.502 2653.171 67.391 0.074 in seawater 0.5% CI-1A 15% HCl 50% dilution 0.75% FCI-XQ 5.411 9558.483 242.785 0.268 in seawater 0.5% CI-1A 15% HCl 50% dilution 0.75% FCI-XR 2.172 3837.03 97.461 0.107 in seawater 0.5% CI-1A 15% HCl 50% dilution 1% FCI-XQ 0.95 1677.221 42.601 0.047 in seawater 1% CI-1A 15% HCl 50% dilution 0.75% FCI-XQ 1.836 3242.628 82.363 0.091 in seawater 1% CI-1A 15% HCl 50% dilution 1% FCI-XP 0.316 557.6606 14.165 0.016 in seawater 1% CI-1A 15% HCl 50% dilution 0.75% FCI-XP 0.874 1543.856 39.214 0.043 in seawater 1% CI-1A 15% HCl 50% dilution 1% FCI-XS 0.154 272.3828 6.919 0.008 in seawater 1% CI-1A 15% HCl 50% dilution 0.75% FCI-XS 0.196 346.0428 8.789 0.01 in seawater 0.75% CI-1A

(47) TABLE-US-00020 TABLE #20 Corrosion test results from tests conducted at 90° C. for a period ranging for 6 hours with a coupon density of 7.86 g/cc having a surface area of 28.922 cm.sup.2 (coupons used were J55 steel) Corrosion Wt loss Fluid Dilution Package (g) Mils/yr mm/year lb/ft2 1.2:1 50% dilution 1.5% FCI-XP 0.135 340.3396 8.645 0.01 HCl-Urea in seawater 0.5% CI-1A 1.2:1 50% dilution 1.5% FCI-XQ 0.296 748.1908 19.004 0.021 HCl-Urea in seawater 0.5% CI-1A 1.2:1 50% dilution 1.5% FCI-XR 0.269 680.932 17.296 0.019 HCl-Urea in seawater 0.5% CI-1A 1.2:1 50% dilution 1.5% FCI-XS 0.252 638.1999 16.21 0.018 HCl-Urea in seawater 0.5% CI-1A

(48) TABLE-US-00021 TABLE #21 Corrosion test results from tests conducted at 90° C. for a period ranging for 6 hours with a coupon density of 7.86 g/cc having a surface area of 30.199 cm.sup.2 (coupons used were N80 steel) Corrosion Wt loss Fluid Dilution Package (g) Mils/yr mm/year lb/ft2 1.2:1 50% dilution 1.5% FCI-XP 0.188 455.7459 11.576 0.013 HCl-Urea in seawater 0.5% CI-1A 1.2:1 50% dilution 1.5% FCI-XQ 0.331 802.5196 20.384 0.022 HCl-Urea in seawater 0.5% CI-1A 1.2:1 50% dilution 1.5% FCI-XR 0.351 851.1939 21.62 0.024 HCl-Urea in seawater 0.5% CI-1A 1.2:1 50% dilution 1.5% FCI-XS 0.298 721.3959 18.323 0.02 HCl-Urea in seawater 0.5% CI-1A

(49) TABLE-US-00022 TABLE #22 Corrosion test results from tests conducted at 90° C. for a period ranging for 6 hours with a coupon density of 7.86 g/cc having a surface area of 30.199 cm.sup.2 (various steel coupons were used) Corrosion Wt loss Surface area Metal Fluid Package (g) (cm.sup.2) Mils/yr mm/year lb/ft2 L80-13CR 1.2:1 2.5% FCI-XP 0.028 8.47 244.3424 6.206 0.007 HCl-Urea 5% CI-1A (Diluted in 50% seawater) L80-13CR 1.2:1 5% FCI-XP 0.022 8.47 185.6311 4.715 0.005 HCl-Urea 5% CI-1A (Diluted in 50% seawater) L80-13CR 1.2:1 5% FCI-XR 0.019 8.47 161.4559 4.101 0.005 HCl-Urea 5% CI-1A (Diluted in 50% seawater) L80-13CR 1.2:1 5% FCI-XQ 0.02 8.47 171.8167 4.364 0.005 HCl-Urea 5% CI-1A (Diluted in 50% seawater) L80-13CR 1.2:1 5% FCI-XS 0.015 8.47 127.7833 3.246 0.004* HCl-Urea 5% CI-1A (Diluted in 50% seawater) L80-13CR 1.2:1 5% FCI-XO 0.044 8.47 376.4426 9.562 0.011 HCl-Urea 5% CI-1A (Diluted in 50% seawater) J55 1.2:1 1.5% FCI-XM 0.294 28.922 743.8923 18.895 0.021 HCl-Urea 1% CI-1A (Diluted in 50% seawater) N80 1.2:1 1.5% FCI-XM 0.363 30.199 878.0737 22.303 0.025 HCl-Urea 1% CI-1A (Diluted in 50% seawater) J55 15% HCl 0.75% FCI-XM 0.308 28.922 777.7746 19.755 0.022 0.5% CI-1A N80 15% HCl 0.75% FCI-XM 0.98 30.199 2373.414 60.285 0.066 0.5% CI-1A J55 1.2:1 1.5% FCI-XL 0.117 28.922 295.079 7.495 0.008 HCl-Urea 1% CI-1A (Diluted in 50% seawater) N80 1.2:1 1.5% FCI-XL 0.156 30.199 377.5281 9.589 0.011 HCl-Urea 1% CI-1A (Diluted in 50% seawater) N80 15% HCl 1.5% FCI-XM 0.238 30.199 577.3104 14.664 0.016 1% CI-1A *no pits, but checkered surface

(50) TABLE-US-00023 TABLE #23 Corrosion test results from tests conducted at 90° C. for a period ranging for 6 hours with a coupon density of 7.86 g/cc Steel Corrosion Wt loss type Fluid Dilution Package (g) Surface area Mils/yr mm/year lb/ft2 1018 1.2:1 50% dilution 1.5% FCI-XM 0.338 41.4 597.5818 15.179 0.017 HCl-Urea in seawater 1% CI-1A N80 1.2:1 50% dilution 2% FCI-XM 0.196 30.199 475.6031 12.080 0.013 HCl-Urea in seawater 1% CI-1A J55 1.2:1 50% dilution 2% FCI-XM 0.191 28.922 482.9484 12.267 0.014 HCl-Urea in seawater 1% CI-1A L80 1.2:1 50% dilution 2% FCI-XM 0.305 30.199 738.8314 18.766 0.021 HCl-Urea in seawater 1% CI-1A N80 1.2:1 50% dilution 1.5% FCI-XL 0.148 30.199 357.9131 9.091 0.010 HCl-Urea in seawater 1% CI-1A J55 1.2:1 50% dilution 1.5% FCI-XL 0.115 28.922 290.0219 7.367 0.008 HCl-Urea in seawater 1% CI-1A L80 1.2:1 50% dilution 1.5% FCI-XL 0.115 30.199 278.2423 7.067 0.008 HCl-Urea in seawater 1% CI-1A

(51) TABLE-US-00024 TABLE 24 Corrosion testing results carried on various steel coupons (having a surface are of 8.47 cm.sup.2) with a metal density of 7.86 g/cc Temp Corrosion Run time Coupon Fluid ° C. Package (hours) Mils/yr Mm/year Lb/ft2 Pit Index L80-13CR 90% 4.5:1 90 5% FCI-XM 6 285.7855776 7.259 0.008 HCl-Lysine 5% CI-1A L80-13CR 90% 4.5:1 90 7.5% FCI-XM 6 240.0253492 6.097 0.007 HCl-Lysine 7.5% CI-1A L80-13CR 90% 4.5:1 90 4% FCI-XM 6 297.8731851 7.566 0.008 HCl-Lysine 4% CI-1A L80-13CR 90% 4.5:1 90 3% FCI-XM 6 282.3319754 7.171 0.008 HCl-Lysine 3% CI-1A 2507 90% 4.5:1 90 7.5% FCI-XM 6 898.7999585 22.830 0.025 few blisters HCl-Lysine 7.5% CI-1A 2507 90% 4.5:1 90 4% FCI-XM 6 2206.851771 56.054 0.062 many blisters HCl-Lysine 4% CI-1A 2507 90% 4.5:1 90 7.5% FCI-XM 3 383.3498382 9.737 0.005 HCl-Lysine 7.5% CI-1A 2507 90% 4.5:1 90 7.5% FCI-XM 4 314.7094956 7.994 0.006 HCl-Lysine 7.5% CI-1A 2507 90% 4.5:1 90 7.5% FCI-XM 5 446.5507575 11.342 0.010 HCl-Lysine 7.5% CI-1A 2507 90% 4.5:1 90 5% FCI-XM-AZ 5 771.8800797 19.606 0.018 many blisters HCl-Lysine 5% CI-1A L80-13CR 50% 4.5:1 90 5% FCI-XM 6 186.4945159 4.737 0.005 HCl-Lysine 5% CI-1A L80-13CR 50% 4.5:1 90 7.5% FCI-XM 6 197.7187229 5.022 0.006 HCl-Lysine 7.5% CI-1A 2507 50% 4.5:1 90 5% FCI-XM 5 782.2408861 19.869 0.018 HCl-Lysine 5% CI-1A 2507 50% 4.5:1 90 7.5% FCI-XM 5 662.0555314 16.816 0.015 HCl-Lysine 7.5% CI-1A 2507 50% 4.5:1 90 7.5% FCI-XM 6 677.7694212 17.215 0.019 HCl-Lysine 7.5% CI-1A 2507 15% HCl 90 5% FCI-XM 6 512.8599187 13.027 0.014 5% CI-1A 2507 15% HCl 90 7.5% FCI-XM 6 427.3832656 10.856 0.012 7.5% CI-1A 2507 75% 4.5:1 90 5% FCI-XM 5 44166.04569 1121.818 1.033 HCl-Lysine 5% CI-1A 2507 75% 4.5:1 90 7.5% FCI-XM 5 44124.60246 1120.765 1.032 HCl-Lysine 7.5% CI-1A 2507 75% 4.5:1 90 7.5% FCI-XM 6 37018.298 940.265 1.039 HCl-Lysine 7.5% CI-1A

(52) TABLE-US-00025 TABLE 25 Corrosion testing results carried on 1018 steel coupons with a metal density of 7.86 g/cc (surface area of 41.4 cm.sup.2) for a run time of 6 hours Temp Corrosion Fluid ° C. Package Mils/yr Mm/year Lb/ft2 Pit Index 15% HCl 110 1.5 FCI-XM 316.1902066 8.031 0.009 1% CI-1A 15% HCl 110 2 FCI-XM 351.1654362 8.920 0.010 1% CI-1A 15% HCl 110 2 FCI-XM 312.1274274 7.928 0.009 1.5% CI-1A 15% HCl 90 1.5% FCI-XM 2327.972477 59.131 0.065 1% CI-1A 15% HCl 70 1% FCI-XM 141.667344 3.598 0.004 0.75% CI-1A 15% HCl 90 1.5% FCI-XM 631.1439153 16.031 0.018 1% CI-1A 15% HCl 90 2 FCI-XM 372.7158302 9.467 0.010 1% CI-1A 15% HCl 90 2 FCI-XM 322.7259819 8.197 0.009 1.5% CI-1A 15% HCl 115 2 FCI-XM 5645.673293 143.400 0.158 1.5% CI-1A

(53) TABLE-US-00026 TABLE 26 Corrosion testing results carried using 15% HCl on J55 or L80 steel coupons with a metal density of 7.86 g/cc Temp Corrosion Surface area Run time Coupon ° C. Package (cm2) (hours) Mils/yr Mm/year Lb/ft2 J55 90 1.5 FCI-XM 28.922 6 472.0757814 11.991 0.013 1.0% CI-1A J55 115 1.5 FCI-XM 28.922 6 1225.070788 31.117 0.034 1.0% CI-1A J55 115 2 FCI-XM 28.922 6 612.6618203 15.562 0.017 1.5% CI-1A L80 115 2 FCI-XM 30.199 24 463.2528848 11.767 0.052 1.5% CI-1A

(54) TABLE-US-00027 TABLE 27 Corrosion testing results carried on Q-125 steel coupons (having a surface are of 45.71 cm.sup.2) for a run time of 6 hours at various temperatures Temp Corrosion Fluid ° C. Package Mils/yr Mm/year Lb/ft2 Pit Index 90% 4.5:1 90 2.5 FCI-XM 258.0589172 6.555 0.007 No pits HCl-Lysine 2.0% CI-1A 90% 4.5:1 90 1.75 FCI-XM 257.4189695 6.538 0.007 Yes HCl-Lysine 2.0% CI-1A 50% 4.5:1 90 2.5 FCI-XM 368.1299246 9.351 0.010 Yes HCl-Lysine 2.0% CI-1A 50% 4.5:1 90 2.75 FCI-XM 333.8927217 8.481 0.009 Yes HCl-Lysine 2.5% CI-1A 50% 4.5:1 90 1.0 FCI-XM 190.8644068 4.848 0.005 Yes HCl-Lysine 1.0% CI-1A 21% MSA 90 1.5 FCI-XM 255.8191002 6.498 0.007 No pits 1.0% CI-1A 90% 4.5:1 120 3.0 FCI-XM 777.2165032 19.741 0.022 Yes HCl-Lysine 3.0% CI-1A 90% 4.5:1 120 5.0 FCI-XM 705.3823719 17.917 0.020 Yes HCl-Lysine 5.0% CI-1A 21% MSA 120 2.0 FCI-XM 1058.793499 26.893 0.030 Yes 1.5% CI-1A 21% MSA 120 2.5 FCI-XM 457.7226051 11.626 0.013 Yes 2.0% CI-1A 21% MSA 90 2.25 FCI-XM 213.7425377 5.429 0.006 No pits 2.0% CI-1A 50% 4.5:1 90 3.5 FCI-XM 353.8910879 8.989 0.010 Yes HCl-Lysine 3.5% CI-1A

(55) TABLE-US-00028 TABLE 28 Corrosion testing results carried on various steel coupons at a temperature of 90° C. Corrosion Coupon Fluid Package Surface area Run time Mils/yr Mm/year Lb/ft2 N80 Spent 50% 4.5:1 1.75% FCI-XM 30.199 24 9.081015776 0.231 0.001 HCl-Lysine 0.75% CI- N80 Spent 90% 4.5:1 1.75% FCI-XM 30.199 24 14.0453044 0.357 0.002 HCl-Lysine 0.75% CI- Super Duplex Spent 90% 4.5:1 1.75% FCI-XM 33.497 6 1.309908806 0.033 0.000 2507 HCl-Lysine 0.75% CI- Super Duplex Spent 90% 4.5:1 1.75% FCI-XM 33.497 6 3.274772014 0.083 0.000 2507 HCl-Lysine 0.75% CI-

(56) TABLE-US-00029 TABLE 29 Corrosion testing results carried out using 15% HCl on 1018 steel coupons (having a surface are of 41.4 cm.sup.2) for a run time of 6 hours at various temperatures Temp Corrosion ° C. Package Mils/yr Mm/year Lb/ft2 120 1.0% FCI-XL 203.3156021 5.164 0.006 1.0% CI-1A 120 1.5% FCI-XL 189.8907666 4.823 0.005 1.0% CI-1A 120 2.0% FCI-XL 167.9870874 4.267 0.005 1.0% CI-1A 120 1.0% FCI-XL 151.3826855 3.845 0.004 1.75% CI-1A 120 1.5% FCI-XL 130.7155044 3.320 0.004 1.75% CI-1A 120 2.0% FCI-XL 137.6045648 3.495 0.004 1.75% CI-1A 90 0.5% FCI-XL 140.430846 3.567 0.004 0.5% CI-1A 90 1.0% FCI-XL 91.85413824 2.333 0.003 0.5% CI-1A 90 1.5% FCI-XL 72.07017 1.831 0.002 0.5% CI-1A 90 0.5% FCI-XL 132.4819302 3.365 0.004 0.75% CI-1A 90 1.0% FCI-XL 81.25558383 2.064 0.002 0.75% CI-1A 90 1.5% FCI-XL 63.59132647 1.615 0.002 0.75% CI-1A 90 0.3% FCI-XL 4466.230829 113.442 0.125 0.2% CI-1A 90 0.5% FCI-XL 278.2120533 7.067 0.008 0.2% CI-1A 120 1.0% FCI-XL 316.5434918 8.040 0.009 0.5% CI-1A 120 1.5% FCI-XL 250.6558119 6.367 0.007 0.75% CI-1A 90 0.4% FCI-XL 960.0523872 24.385 0.027 0.2% CI-1A 120 0.75% FCI-XL 279.4485513 7.098 0.008 0.5% CI-1A 120 1.0% FCI-XL 275.032487 6.986 0.008 0.25% CI-1A

(57) TABLE-US-00030 TABLE 30 Corrosion testing results carried out using 15% HCl on Q-125 steel coupons (having a surface are of 45.71 cm.sup.2) for a run time of 6 hours at various temperatures Temp Corrosion Surface area Coupon (° C.) Package (cm2) Mils/yr Mm/year Lb/ft2 Pit index L80 90 0.5% FCI-XL 30.199 312.8712635 7.947 0.009 2 0.2% CI-1A N80 90 0.5% FCI-XL 30.199 202.6882721 5.148 0.006 3 0.2% CI-1A J55 90 0.5% FCI-XL 28.922 215.1775522 5.466 0.006 0 0.2% CI-1A P110 90 0.5% FCI-XL 28.922 308.2273045 7.829 0.009 0 0.2% CI-1A QT-900 90 0.5% FCI-XL 34.31 143.8728277 3.654 0.004 1 0.2% CI-1A 1018CS 90 0.5% FCI-XL 37.712 499.530509 12.688 0.014 2 0.2% CI-1A L80 120 1.0% FCI-XL 30.199 985.3507518 25.028 0.028 6 0.25% CI-1A N80 120 1.0% FCI-XL 30.199 629.3749334 15.986 0.018 7 0.25% CI-1A J55 120 1.0% FCI-XL 28.922 356.0164436 9.043 0.010 1 0.25% CI-1A P110 120 1.0% FCI-XL 28.922 614.9374935 15.619 0.017 1 0.25% CI-1A QT-900 120 1.0% FCI-XL 34.31 600.8555574 15.262 0.017 2 0.25% CI-1A 1018CS 120 1.0% FCI-XL 37.712 776.2502436 19.717 0.022 1 0.25% CI-1A N80 80 1.5% FCI-XM 30.199 311.418301 7.910 0.009 (w/6-3*) 1.0% CI-1A N80 80 1.5% FCI-XM 30.199 501.2720708 12.732 0.014 (w/6-3*) wherein 6-3 refers to a short chain ethoxylate present as solvent in the corrosion package. It replaces entirely the initial solvent used in the CI package, i.e. methanol.

(58) TABLE-US-00031 TABLE 31 Corrosion testing results carried out using 90% MEA:HCl (in a 1:4 ratio) on L80-13CR steel coupons (having a density of 7.86 g/cc and surface are of 8.47 cm.sup.2) for a run time of either 5 or 6 hours at various temperatures Temp Corrosion Initial wt. Final wt. Loss wt. ° C. Package (g) (g) (g) Run time Mils/yr mm/year lb/ft2 Pit Index 90 3.0% FCI-XM 4.5062 4.4855 0.021 6 178.7239111 4.540 0.005 3.0% CI-1A 90 5.0% FCI-XM 4.5087 4.4888 0.020 6 171.8167068 4.364 0.005 5.0% CI-1A 110 3.0% FCI-XM 4.4348 4.3916 0.043 6 372.9890318 9.474 0.010 3.0% CI-1A 110 5.0% FCI-XM 4.4964 4.4538 0.043 6 367.8086286 9.342 0.010 5.0% CI-1A 90 2.5% FCI-XM 4.5042 4.4814 0.023 6 196.8553223 5.000 0.006 N 2.0% CI-1A 90 2.5% FCI-XM 4.4481 4.4267 0.021 6 184.7677148 4.693 0.005 N 2.5% CI-1A 110 2.5% FCI-XM 4.4813 4.4334 0.048 6 413.568857 10.505 0.012 N 2.5% CI-1A 110 3.0% FCI-XM 4.4714 4.4397 0.032 6 273.6979701 6.952 0.008 N 3.0% CI-1A 110 2.5% FCI-XM 4.5117 4.4957 0.016 5 165.772903 4.211 0.004 N 2.5% CI-1A 110 3.0% FCI-XM 4.4393 4.4127 0.027 5 275.5974513 7.000 0.006 N 3.0% CI-1A

(59) Additionally, corrosion inhibition packages according to preferred embodiments of the present invention will allow the end user to utilize synthetic and modified acids that have down-hole performance advantages, transportation and storage advantages as well as the health, safety and environmental advantages. The person skilled in the art will also understand that the corrosion package according to the present invention is also useful when utilized with conventional acid systems.

(60) In addition to stability at high temperatures and desirable corrosion rates as discussed above, the use of synthetic and modified acids along with a corrosion package according to a preferred embodiment of the present invention, allows for at least one of the following advantages: reduction in skin corrosiveness, a more controlled or methodical spending or reacting property, minimizing near well bore damage typically caused by an ultra-aggressive reaction with the formation typically caused by HCl and increasing formation penetration providing superior production over time.

Uses of Corrosion Inhibition Packages According to Preferred Embodiments of the Present Invention

(61) The uses (or applications) of the corrosion inhibition packages according to the present invention when combined (or mixed) with acidic compositions upon dilution of the latter ranging from approximately 1 to 90% dilution, include, but are not limited to: injection/disposal well treatments; matrix acid squeezes, soaks or bullheads; acid fracturing, acid washes; fracturing spearheads (breakdowns); pipeline scale treatments, cement breakdowns or perforation cleaning; pH control; and de-scaling applications. As would be understood by the person skilled in the art, the methods of use generally comprise the following steps: providing a composition comprising a corrosion inhibitor package according to a preferred embodiment of the present; mixing said package with an acid composition; exposing a surface (such as a metal surface) to the acid composition comprising the package; allowing the acid composition a sufficient period of time to act upon said surface; and optionally, removing the acid composition when the exposure time has been determined to be sufficient for the operation to be complete or sufficiently complete. Another method of use comprises: injecting the acid composition comprising the package into a well and allowing sufficient time for the acid composition to perform its desired function. Yet another method of use comprises: exposing the acid composition comprising the package to a body of fluid (typically water) requiring a decrease in the pH and allowing sufficient exposure time for the acid composition to lower the pH to the desired level.

(62) One of the advantages of the use of a synthetic acid composition using a corrosion inhibition package according to a preferred embodiment of the present invention includes: the reduction of the total loads of acid, and the required number of tanks by delivering concentrated product to location and diluting with fluids available on location (with low to high salinity production water).

(63) While the foregoing invention has been described in some detail for purposes of clarity and understanding, it will be appreciated by those skilled in the relevant arts, once they have been made familiar with this disclosure that various changes in form and detail can be made without departing from the true scope of the invention in the appended claims.