NOVEL 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. An aqueous synthetic or modified acidic composition comprising a corrosion inhibitor package, an acid composition comprising an acid selected from the group consisting of mineral acids; organic acids, synthetic acids; modified acids; complexed acids and combinations thereof, and wherein said corrosion inhibitor package comprises a terpene; a cinnamaldehyde or a derivative thereof; at least one amphoteric surfactant; an anionic surfactant which is ß-Alanine, N-(2-carboxyethyl)-N-dodecyl-, sodium salt (1:1); and a solvent; and wherein the volume % of the corrosion inhibition package in the aqueous synthetic or modified acidic composition ranges from 0.1 to 10%.

2. The aqueous synthetic or modified acidic composition according to claim 1 further comprising a corrosion inhibitor intensifier selected from the group consisting of a metal iodide or iodate, aluminum chloride, calcium chloride, bismuth chloride, magnesium chloride, and combinations thereof.

3. The aqueous synthetic or modified acidic composition according to claim 1, 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.

4. The aqueous synthetic or modified acidic composition according to claim 3, wherein the amphoteric surfactant is cocamidopropyl betaine.

5. The aqueous synthetic or modified acidic composition according to claim 1, wherein the terpene is selected from the group consisting of citral and ocimene.

6. The aqueous synthetic or modified acidic composition according to claim 1, wherein the acid is selected from the group consisting of hydrochloric acid; 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.

7. The aqueous synthetic or modified acidic composition according to claim 1, wherein the acid composition comprises lysine and hydrochloric acid in a molar ratio of not less than 1:12.

8. The aqueous synthetic or modified acidic composition according to claim 1, wherein the acid composition comprises urea and hydrochloric acid in a molar ratio of not less than 0.1:1.

9. The aqueous synthetic or modified acidic composition according to claim 2, wherein the corrosion inhibitor intensifier is potassium iodide and the potassium iodide is present in an amount ranging from 0.1 to 1.5% vol./vol. of the aqueous synthetic or modified acidic composition.

10. A corrosion inhibition package for use with an aqueous synthetic or modified acidic composition comprising a corrosion inhibitor component, wherein 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 ß-Alanine, N-(2-carboxyethyl)-N-dodecyl-, sodium salt (1:1); and a solvent.

11. The corrosion inhibition package according to claim 10 wherein 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, 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, and the solvent is present in an amount ranging from 25% to 80% by volume of the total volume of the corrosion inhibition package.

12. The corrosion inhibition package according to claim 11, wherein the terpene is selected from the group consisting of citral and ocimene, and the at least one amphoteric surfactant is cocamidopropyl betaine.

13. The corrosion inhibition package according to claim 12, wherein the solvent is selected from the group consisting of: isopropanol; methanol; ethanol; 2-butoxyethanol; diethylene glycol; a short chain ethoxylate; and combinations thereof.

14. The corrosion inhibition package according to claim 13 comprising 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. The corrosion inhibition package according to claim 1, wherein the corrosion inhibitor component is a water-soluble corrosion inhibitor component.

16. 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; a cinnamaldehyde or a derivative thereof; at least one amphoteric surfactant; an anionic surfactant which is ß-Alanine, N-(2-carboxyethyl)-N-dodecyl-, sodium salt (1:1); and a solvent.

17. The corrosion inhibition package according to claim 16, wherein the corrosion inhibitor component is a water-soluble corrosion inhibitor component.

18. A method of making the aqueous synthetic or modified acidic composition of claim 1, said method comprising the steps of: - preparing the corrosion inhibition package by o mixing the solvent and the at least one amphoteric surfactant to form a solvent-surfactant solution; and o dispersing the terpene in the solvent-surfactant solution; and - mixing the corrosion inhibition package with the acid composition.

19. A method of using the aqueous synthetic or modified acidic composition of claim 1 in the oil industry, said method comprising the steps of: preparing the aqueous synthetic or modified acidic composition of claim 1; introducing the aqueous synthetic or modified acidic composition while performing an activity in the oil industry, wherein 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

[0066] 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.

[0067] 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: [0068] a terpene; [0069] cinnamaldehyde or a derivative thereof; [0070] at least one amphoteric surfactant; and [0071] a solvent.

[0072] Preferably, the corrosion inhibition package is used with an acidic composition such as a synthetic acid composition comprising:

[0073] 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.

[0074] 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.

[0075] 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.

[0076] 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.

[0077] The terpenes considered by the inventors to achieve desirable corrosion inhibition results comprise: monoterpenes (acyclic); monocyclic terpenes; and beta-Ionone. Exemplary but nonlimiting 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.

[0078] 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.

[0079] 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.

[0080] 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- methylsulfate; 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.

[0081] 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

[0082] A preferred embodiment can refer to a corrosion inhibition package comprising cocamidopropyl betaine and β-Alanine, N-(2-carboxyethyl)-N-dodecyl-, sodium salt (1:1).

[0083] 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.

[0084] 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.

[0085] Also, preferably, the corrosion inhibition package is used with an acidic composition such as a modified acid composition comprising:

[0086] 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.

[0087] 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 .sub.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.

[0088] 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

[0089] 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.

[0090] 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).

[0091] To prepare an aqueous acidic composition of a modified acid, lysine monohydrochloride 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.

[0092] 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.

[0093] 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.

Corrosion Inhibition Package Formulations

[0094] 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).

[0095] 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).

TABLE-US-00001 List of Component and Content in Corrosion Inhibition Packages FCI-XV to XFCI-XP (All figures are in vol %) Compound FCI-XV FCI-XT FCI-XS FCI-XR FCI-XQ FCI-XO FCI-XP Cocamidopropyl betaine 10 10 10 10 5 5 10 ß -Alanine, N-(2-carboxyethyl)-N-dodecyl-, sodium salt (1:1) 10 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

TABLE-US-00002 List of Component and Content in Corrosion Inhibition Packages FCI-XN to FCI- XK (All figures are in vol %) Compound FCI-XN FCI-XM FCI-XL FCI-XI FCI-XJ FCI-XK Cocamidopropyl betaine 10 5 5 10 5 5 β.-Alanine, N-(2-carboxyethyl)-N-dodecyl-, sodium salt (1:1) 10 5 10 5 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

[0096] X 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.

[0097] The following abbreviations are used in the corrosion results tables: CI-1A - 10% aqueous KI solution; ZA - Cinnamaldehyde; and CA - Citral.

TABLE-US-00003 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) Fluid Dilution Corrosion Package Wt loss (g) Mils/yr mm/year lb/ft2 1.2 : 1 HCl-Urea 50% dilution in seawater 1% ZA 1% CI-1A 0.168 296.053 7.52 0.008 1.2 : 1 HCl-Urea 50% dilution in seawater 1% FCI-XT 1% CI-1A 0.54 954.5765 24.246 0.027 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XT 1% CI-1A 0.439 775.1076 19.688 0.022 1.2 : 1 HCl-Urea 50% dilution in seawater 1% FCI-XS 1% CI-1A 0.18 318.6632 8.094 0.009 1.2 : 1 HCl-Urea HCl-Urea 50% dilution in seawater 1% FCI-XS 0.5% CI-1A 0.238 420.7626 10.687 0.012 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XS 1% CI-1A 0.151 266.9069 6.779 0.007 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XS 0.5% CI-1A 0.185 327.4953 8.318 0.009 1.2 : 1 HCl-Urea 50% dilution in seawater 2.5% FCI-XS 1% CI-1A 0.124 218.6835 5.555 0.006 1.2 : 1 HCl-Urea 50% dilution in seawater 2.5% FCI-XS 0.5% CI-1A 0.149 263.904 6.703 0.007 1.2 : 1 HCl-Urea 50% dilution in seawater 1% FCI-XR 1% CI-1A 0.235 415.2867 10.548 0.012 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XR 1% CI-1A 0.153 270.6164 6.874 0.008 1.2 : 1 HCl-Urea 50% dilution in seawater 1% FCI-XQ 1% CI-1A 0.274 484.3539 12.303 0.014 1.2 : 1 HCl-Urea 50% dilution in seawater 1% FCI-XQ 0.5% CI-1A 0.341 602.5278 15.304 0.017 1.2 : 1 HCl-Urea Diluted in 50% seawater 1.5% FCI-XQ 1% CI-1A 0.18 318.1333 8.081 0.009 1.2 : 1 HCl-Urea Diluted in 50% seawater 1.5% FCI-XQ 0.5% CI-1A 0.255 450.0853 11.432 0.013 1.2 : 1 HCl-Urea Diluted in 50% seawater 1% FCI-XR 0.5% CI-1A 0.312 551.3015 14.003 0.015 1.2 : 1 HCl-Urea Diluted in 50% seawater 1.5% FCI-XR 1% CI-1A 0.182 321.6661 8.17 0.009 1.2 : 1 HCl-Urea Diluted in 50% seawater 1.5% FCI-XR 0.5% CI-1A 0.213 375.7188 9.543 0.011

Where the ratios are molar ratios and where CI-1A indicates potassium iodide present as intensifier.

TABLE-US-00004 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) Fluid Corrosion Package Wt loss (g) Mils/yr mm/year lb/ft2 21% MSA (diluted in seawater) 1.5% FCI-XQ 1% CI-1A 0.125 220.8032 5.608 0.006 21% MSA (diluted in seawater) 1.5% FCI-XR 1% CI-1A 0.1 176.4659 4.482 0.005 21% MSA (diluted in seawater) 1.5% FCI-XS 1% CI-1A 0.081 143.6104 3.648 0.004 21% MSA (diluted in seawater) 1.5% FCI-XT 1% CI-1A 1.073 1895.022 48.134 0.053 21% MSA (diluted in seawater) 1.5% FCI-XP 1% CI-1A 0.048 85.49501 2.172 0.002

Wherein the 21% MSA solution diluted in seawater is prepare by adding 1 part volume of 42% methanesulfonic acid to 1 part volume seawater.

TABLE-US-00005 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) Fluid Dilution Corrosion Package Wt loss (g) Mils/yr mm/year lb/ft2 1.2 : 1 HCl-Urea 50% dilution in seawater 1% FCI-XS 1% CI-1A 0.171 301.3522 7.654 0.008 1.2 : 1 HCl-Urea 50% dilution in seawater 1% FCI-XS 0.5% CI-1A 0.226 399.9188 10.158 0.011 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XS 1% CI-1A 0.127 224.6894 5.707 0.006 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XS 0.5% CI-1A 0.147 260.3712 6.613 0.007

TABLE-US-00006 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) Fluid Corrosion Package Wt loss (g) Mils/yr mm/year lb/ft2 21% MSA (diluted in seawater) 1.5% FCI-XQ 1% CI-1A 2.249 3971.808 100.884 0.111 21% MSA (diluted in seawater) 1.5% FCI-XR 1% CI-1A 1.763 3114.032 79.096 0.087 21% MSA (diluted in seawater) 1.5% FCI-XS 1% CI-1A 0.237 418.8195 10.638 0.012 21% MSA (diluted in seawater) 1.5% FCI-XT 1% CI-1A 2.849 5032.37 127.822 0.141 21% MSA (diluted in seawater) 1.5% FCI-XP 1% CI-1A 0.114 201.9025 5.128 0.006

TABLE-US-00007 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) Fluid Dilution Corrosion Package Wt loss (g) Time (hours) Mils/yr mm/year lb/ft2 HCR-2000N 50% dilution in seawater 5% FCI-XR 5% CI-1A 0.66 4 2785.604 70.754 0.044 HCR-2000N 50% dilution in seawater 5% FCI-XP 5% CI-1A 0.459 4 1934.108 49.126 0.03

TABLE-US-00008 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) Fluid Dilution Corrosion Package Wt loss (g) Mils/yr mm/year lb/ft2 1.2 : 1 HCl-Urea 50% dilution in seawater 1% FCI-XQ 1% CI-1A 0.076 133.3651 3.387 0.004 1.2 : 1 HCl-Urea 50% dilution in seawater 1% FCI-XQ 0.5% CI-1A 0.09 158.2717 4.02 0.004 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XQ 1% CI-1A 0.076 133.5418 3.392 0.004 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XQ 0.5% CI-1A 0.087 153.679 3.903 0.004 1.2 : 1 HCl-Urea 50% dilution in seawater 1% FCI-XR 1% CI-1A 0.081 142.3739 3.616 0.004 1.2 : 1 HCl-Urea 50% dilution in seawater 1% FCI-XR 0.5% CI-1A 0.097 171.1667 4.348 0.005 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XR 1% CI-1A 0.076 133.5418 3.392 0.004 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XR 0.5% CI-1A 0.091 160.7447 4.083 0.005 1.2 : 1 HCl-Urea 50% dilution in seawater 1% FCI-XS 1% CI-1A 0.077 136.0148 3.455 0.004 1.2 : 1 HCl-Urea 50% dilution in seawater 1% FCI-XS 0.5% CI-1A 0.097 170.8134 4.339 0.005 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XS 1% CI-1A 0.065 114.9943 2.921 0.003 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XS 0.5% CI-1A 0.07 124.0031 3.15 0.003

TABLE-US-00009 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) Fluid Dilution Corrosion Package Wt loss (g) Mils/yr mm/year lb/ft2 4.5 : 1 HCl-Lysine 50% dilution in seawater 1.5% FCI-XQ 1% CI-1A 0.463 817.5018 20.765 0.023 4.5 : 1 HCl-Lysine 50% dilution in seawater 1.5% FCI-XR 1% CI-1A 0.176 311.4209 7.91 0.009 4.5 : 1 HCl-Lysine 50% dilution in seawater 1.5% FCI-XS 1% CI-1A 0.157 276.6223 7.026 0.008 4.5 : 1 HCl-Lysine 50% dilution in seawater 1.5% FCI-XP 1% CI-1A 0.238 421.1159 10.696 0.012 4.5 : 1 HCl-Lysine 50% dilution in seawater 1.5% FCI-XT 1% CI-1A 1.12 1978.927 50.265 0.055

TABLE-US-00010 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) Fluid Dilution Corrosion Package Wt loss (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 HCl-Urea 50% dilution in seawater 1.5% FCI-XP 1% CI-1A 0.119 300.3889 7.63 0.008 no pits 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XQ 1% CI-1A 0.218 551.4715 14.007 0.015 no pits 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XR 1% CI-1A 0.216 546.6673 13.885 0.015 no pits 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XS 1% CI-1A 0.186 470.8115 11.959 0.013 no pits

TABLE-US-00011 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) Fluid Dilution Corrosion Package Wt loss (g) Mils/yr mm/year lb/ft2 observations HCl-Urea (control) none none 0.117 304.9971 7.747 0.009 HCl-Urea 50% dilution in seawater none 0.370 963.1762 24.465 0.027 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XP 1% CI-1A 0.128 310.2075 7.879 0.009 few pits on side/back 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XQ 1% CI-1A 0.278 672.4795 17.081 0.019 no pits 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XR 1% CI-1A 0.247 598.3784 15.199 0.017 no pits 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XS 1% CI-1A 0.206 500.0613 12.702 0.014 no pits

TABLE-US-00012 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) Fluid Dilution Corrosion Package Wt loss (g) Mils/yr mm/year lb/ft2 obseevations 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XP 1% CI-1A 0.153 369.779 9.392 0.01 few pits on side/back 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XQ 1% CI-1A 0.289 698.875 17.751 0.02 no pits 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XR 1% CI-1A 0.296 716.0684 18.188 0.02 no pits 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XS 1% CI-1A 0.232 562.5387 14.288 0.016 no pits

TABLE-US-00013 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) Fluid Dilution Corrosion Package Wt loss (g) Mils/yr mm/year lb/ft2 obseevations 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XP 1% CI-1A 1.575 3983.187 101.173 0.078 no pits 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XQ 1% CI-1A 0.645 1630.141 41.406 0.046 Yes, some pits on sides 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XR 1% CI-1A 0.77 1945.954 49.427 0.055 Yes, some pits on sides 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XS 1% CI-1A 0.387 978.5395 24.855 0.027 no pits

TABLE-US-00014 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) Fluid Dilution Corrosion Package Wt loss (g) Surface area (cm2) Mils/yr mm/year lb/ft2 4.5 : 1 HCl-Lysine 50% dilution in seawater 1.5% FCI-XQ 1% CI-1A 1.399 28.922 3537.913 89.863 0.099 4.5 : 1 HCl-Lysine 50% dilution in seawater 1.5% FCI-XR 1% CI-1A 1.114 41.4 1966.915 49.96 0.055 4.5 : 1 HCl-Lysine 50% dilution in seawater 1.5% FCI-XS 1% CI-1A 0.336 41.4 592.8125 15.057 0.017 4.5 : 1 HCl-Lysine 50% dilution in seawater 1.5% FCI-XT 1% CI-1A 3.839 41.4 6780.955 172.236 0.19 4.5 : 1 HCl-Lysine 50% dilution in seawater 1.5% FCI-XP 1% CI-1A 0.315 41.4 556.4241 14.133 0.016

TABLE-US-00015 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) Fluid Corrosion Package Wt loss (g) Mils/yr mm/year lb/ft2 15% HCl 1.5% FCI-XP 1% CI-1A 0.075 132.8352 3.374 0.004 15% HCl 2.5% FCI-XP 1% CI-1A 0.068 119.587 3.038 0.003 15% HCl 1.5% FCI-XQ 1% CI-1A 1.121 1980.693 50.31 0.055 15% HCl 2.5% FCI-XQ 1% CI-1A 0.793 1400.069 35.562 0.039 15% HCl 1.5% FCI-XR 1% CI-1A 0.176 310.8909 7.897 0.009 15% HCl 2.5% FCI-XR 1% CI-1A 0.215 380.4881 9.664 0.011 15% HCl 1.5% FCI-XS 1% CI-1A 0.2 353.2851 8.973 0.01 15% HCl 2.5% FCI-XS 1% CI-1A 0.228 402.2151 10.216 0.011

TABLE-US-00016 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) Fluid Dilution Corrosion Package Wt loss (g) Mils/yr mm/year lb/ft2 Observations 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XP 0.5% CI-1A 0.18 435.6466 11.065 0.012 few pits on side/back 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XQ 0.5% CI-1A 0.305 738.8314 18.766 0.021 no pits 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XR 0.5% CI-1A 0.305 738.8314 18.766 0.021 no pits 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XS 0.5% CI-1A 0.317 766.4377 19.468 0.021 no pits

TABLE-US-00017 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) Fluid Dilution Corrosion Package Wt loss (g) Mils/yr mm/year lb/ft2 Observations 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XP 0.5% CI-1A 0.388 981.3209 24.926 0.026 few pits on side/back 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XQ 0.5% CI-1A 0.589 1489.555 37.835 0.042 few pits on side/back 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XR 0.5% CI-1A 0.662 1674.896 42.542 0.047 few pits on side/back 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XS 0.5% CI-1A 0.376 951.2314 24.161 0.027 few pits on side/back

TABLE-US-00018 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) Fluid Dilution Corrosion Package Wt loss (g) Mils/yr mm/year lb/ft2 15% HCl 50% dilution in seawater 1% FCI-XP 1% CI-1A 0.135 239.3507 6.08 0.007 15% HCl 50% dilution in seawater 1% FCI-XP 0.5% CI-1A 0.206 364.0603 9.247 0.01 15% HCl 50% dilution in seawater 0.75% FCI-XP 1% CI-1A 0.094 166.7506 4.235 0.005 15% HCl 50% dilution in seawater 0.75% FCI-XP 0.5% CI-1A 0.242 427.1217 10.849 0.012 15% HCl 50% dilution in seawater 1% FCI-XQ 0.5% CI-1A 1.173 2072.901 52.652 0.058 15% HCl 50% dilution in seawater 1% FCI-XR 0.5% CI-1A 1.204 2126.07 54.002 0.06 15% HCl 50% dilution in seawater 0.75% FCI-XQ 0.5% CI-1A 1.022 1805.11 45.85 0.051 15% HCl 50% dilution in seawater 0.75% FCI-XR 0.5% CI-1A 0.801 1415.084 35.943 0.04

TABLE-US-00019 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) Fluid Dilution Corrosion Package Wt loss (g) Mils/yr mm/year lb/ft2 15% HCl 50% dilution in seawater 1% FCI-XQ 0.5% CI-1A 2.553 4510.215 114.559 0.126 15% HCl 50% dilution in seawater 1% FCI-XR 0.5% CI-1A 1.502 2653.171 67.391 0.074 15% HCl 50% dilution in seawater 0.75% FCI-XQ 0.5% CI-1A 5.411 9558.483 242.785 0.268 15% HCl 50% dilution in seawater 0.75% FCI-XR 0.5% CI-1A 2.172 3837.03 97.461 0.107 15% HCl 50% dilution in seawater 1% FCI-XQ 1% CI-1A 0.95 1677.221 42.601 0.047 15% HCl 50% dilution in seawater 0.75% FCI-XQ 1% CI-1A 1.836 3242.628 82.363 0.091 15% HCl 50% dilution in seawater 1% FCI-XP 1% CI-1A 0.316 557.6606 14.165 0.016 15% HCl 50% dilution in seawater 0.75% FCI-XP 1% CI-1A 0.874 1543.856 39.214 0.043 15% HCl 50% dilution in seawater 1% FCI-XS 1% CI-1A 0.154 272.3828 6.919 0.008 15% HCl 50% dilution in seawater 0.75% FCI-XS 0.75% CI-1A 0.196 346.0428 8.789 0.01

TABLE-US-00020 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) Fluid Dilution Corrosion Package Wt loss (g) Mils/yr mm/year lb/ft2 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XP 0.5% CI-1A 0.135 340.3396 8.645 0.01 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XQ 0.5% CI-1A 0.296 748.1908 19.004 0.021 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XR 0.5% CI-1A 0.269 680.932 17.296 0.019 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XS 0.5% CI-1A 0.252 638.1999 16.21 0.018

TABLE-US-00021 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) Fluid Dilution Corrosion Package Wt loss (g) Mils/yr mm/year lb/ft2 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XP 0.5% CI-1A 0.188 455.7459 11.576 0.013 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XQ 0.5% CI-1A 0.331 802.5196 20.384 0.022 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XR 0.5% CI-1A 0.351 851.1939 21.62 0.024 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XS 0.5% CI-1A 0.298 721.3959 18.323 0.02

TABLE-US-00022 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) Metal Fluid Corrosion Package Wt loss (g) Surface area (cm.sup.2) Mils/yr mm/year lb/ft2 L80-13CR 1.2 : 1 HCl-Urea (Diluted in 50% seawater) 2.5% FCI-XP 5% CI-1A 0.028 8.47 244.3424 6.206 0.007 L80-13CR 1.2 : 1 HCl-Urea (Diluted in 50% seawater) 5% FCI-XP 5% CI-1A 0.022 8.47 185.6311 4.715 0.005 L80-13CR 1.2 : 1 HCl-Urea (Diluted in 50% seawater) 5% FCI-XR 5% CI-1A 0.019 8.47 161.4559 4.101 0.005 L80-13CR 1.2 : 1 HCl-Urea (Diluted in 50% seawater) 5% FCI-XQ 5% CI-1A 0.02 8.47 171.8167 4.364 0.005 L80-13CR 1.2 : 1 HCl-Urea (Diluted in 50% seawater) 5% FCI-XS 5% CI-1A 0.015 8.47 127.7833 3.246 0.004* L80-13CR 1.2 : 1 HCl-Urea (Diluted in 50% seawater) 5% FCI-XO 5% CI-1A 0.044 8.47 376.4426 9.562 0.011 J55 1.2 : 1 HCl-Urea (Diluted in 50% seawater) 1.5% FCI-XM 1% CI-1A 0.294 28.922 743.8923 18.895 0.021 N80 1.2 : 1 HCl-Urea (Diluted in 50% seawater) 1.5% FCI-XM 1% CI-1A 0.363 30.199 878.0737 22.303 0.025 J55 15% HCl 0.75% FCI-XM 0.5% CI-1A 0.308 28.922 777.7746 19.755 0.022 N80 15% HCl 0.75% FCI-XM 0.5% CI-1A 0.98 30.199 2373.414 60.285 0.066 J55 1.2 : 1 HCl-Urea (Diluted in 50% seawater) 1.5% FCI-XL 1% CI-1A 0.117 28.922 295.079 7.495 0.008 N80 1.2 : 1 HCl-Urea (Diluted in 50% seawater) 1.5% FCI-XL 1% CI-1A 0.156 30.199 377.5281 9.589 0.011 N80 15% HCl 1.5% FCI-XM 1% CI-1A 0.238 30.199 577.3104 14.664 0.016 *no pits, but checkered surface

TABLE-US-00023 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 type Fluid Dilution Corrosion Package Wt loss (g) Surface area (cm2) Mils/yr mm/year lb/ft2 1018 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XM 1% CI-1A 0.338 41.4 597.5818 15.179 0.017 N80 1.2 : 1 HCl-Urea 50% dilution in seawater 2% FCI-XM 1% CI-1A 0.196 30.199 475.6031 12.080 0.013 J55 1.2 : 1 HCl-Urea 50% dilution in seawater 2% FCI-XM 1% CI-1A 0.191 28.922 482.9484 12.267 0.014 L80 1.2 : 1 HCl-Urea 50% dilution in seawater 2% FCI-XM 1% CI-1A 0.305 30.199 738.8314 18.766 0.021 N80 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XL 1% CI-1A 0.148 30.199 357.9131 9.091 0.010 J55 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XL 1 % CI-1A 0.115 28.922 290.0219 7.367 0.008 L80 1.2 : 1 HCl-Urea 50% dilution in seawater 1.5% FCI-XL 1% CI-1A 0.115 30.199 278.2423 7.067 0.008

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

TABLE-US-00025 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 Fluid Temp °C Corrosion Package Mils/yr Mm/year Lb/ft2 Pit Index 15% HCl 110 1.5 FCI-XM 1% CI-1A 316.1902066 8.031 0.009 15% HCl 110 2 FCI-XM 1% CI-1A 351.1654362 8.920 0.010 15% HCl 110 2 FCI-XM 1.5% CI-1A 312.1274274 7.928 0.009 15% HCl 90 1.5% FCI-XM 1% CI-1A 2327.972477 59.131 0.065 15% HCl 70 1% FCI-XM 0.75% CI-1A 141.667344 3.598 0.004 15% HCl 90 1.5% FCI-XM 1% CI-1A 631.1439153 16.031 0.018 15% HCl 90 2 FCI-XM 1% CI-1A 372.7158302 9.467 0.010 15% HCl 90 2 FCI-XM 1.5% CI-1A 322.7259819 8.197 0.009 15% HCl 115 2 FCI-XM 1.5% CI-1A 5645.673293 143.400 0.158

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

TABLE-US-00027 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 Fluid Temp °C Corrosion Package Mils/yr Mm/year Lb/ft2 Pit Index 90% 4.5 : 1 HCl-Lysine 90 2.5 FCI-XM 2.0% CI-1A 258.0589172 6.555 0.007 No pits 90% 4.5 : 1 HCl-Lysine 90 1.75 FCI-XM 2.0% CI-1A 257.4189695 6.538 0.007 Yes 50% 4.5 : 1 HCl-Lysine 90 2.5 FCI-XM 2.0% CI-1A 368.1299246 9.351 0.010 Yes 50% 4.5 : 1 HCl-Lysine 90 2.75 FCI-XM 2.5% CI-1A 333.8927217 8.481 0.009 Yes 50% 4.5 : 1 HCl-Lysine 90 1.0 FCI-XM 1.0% CI-1A 190.8644068 4.848 0.005 Yes 21% MSA 90 1.5 FCI-XM 1.0% CI-1A 255.8191002 6.498 0.007 No pits 90% 4.5 : 1 HCl-Lysine 120 3.0 FCI-XM 3.0% CI-1A 777.2165032 19.741 0.022 Yes 90% 4.5 : 1 HCl-Lysine 120 5.0 FCI-XM 5.0% CI-1A 705.3823719 17.917 0.020 Yes 21% MSA 120 2.0 FCI-XM 1.5% CI-1A 1058.793499 26.893 0.030 Yes 21% MSA 120 2.5 FCI-XM 2.0% CI-1A 457.7226051 11.626 0.013 Yes 21% MSA 90 2.25 FCI-XM 2.0% CI-1A 213.7425377 5.429 0.006 No pits 50% 4.5 : 1 HCl-Lysine 90 3.5 FCI-XM 3.5% CI-1A 353.8910879 8.989 0.010 Yes

TABLE-US-00028 Corrosion testing results carried on various steel coupons at a temperature of 90° C. Coupon Fluid Corrosion Package Surface area (cm2) Run time (hours) Mils/yr Mm/year Lb/ft2 N80 Spent 50% 4.5 : 1 HCl-Lysine 1.75% FCI-XM 0.75% CI-1A 30.199 24 9.081015776 0.231 0.001 N80 Spent 90% 4.5 : 1 HCl-Lysine 1.75% FCI-XM 0.75% CI-1A 30.199 24 14.0453044 0.357 0.002 Super Duplex 2507 Spent 90% 4.5 : 1 HCl-Lysine 1.75% FCI-XM 0.75% CI-1A 33.497 6 1.309908806 0.033 0.000 Super Duplex 2507 Spent 90% 4.5 : 1 HCl-Lysine 1.75% FCI-XM 0.75% CI-1A 33.497 6 3.274772014 0.083 0.000

TABLE-US-00029 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 °C Corrosion Package Mils/yr Mm/year Lb/ft2 120 1.0% FCI-XL 1.0% CI-1A 203.3156021 5.164 0.006 120 1.5% FCI-XL 1.0% CI-1A 189.8907666 4.823 0.005 120 2.0% FCI-XL 1.0% CI-1A 167.9870874 4.267 0.005 120 1.0% FCI-XL 1.75% CI-1A 151.3826855 3.845 0.004 120 1.5% FCI-XL 1.75% CI-1A 130.7155044 3.320 0.004 120 2.0% FCI-XL 1.75% CI-1A 137.6045648 3.495 0.004 90 0.5% FCI-XL 0.5% CI-1A 140.430846 3.567 0.004 90 1.0% FCI-XL 0.5% CI-1A 91.85413824 2.333 0.003 90 1.5% FCI-XL 0.5% CI-1A 72.07017 1.831 0.002 90 0.5% FCI-XL 0.75% CI-1A 132.4819302 3.365 0.004 90 1.0% FCI-XL 0.75% CI-1A 81.25558383 2.064 0.002 90 1.5% FCI-XL 0.75% CI-1A 63.59132647 1.615 0.002 90 0.3% FCI-XL 0.2% CI-1A 4466.230829 113.442 0.125 90 0.5% FCI-XL 0.2% CI-1A 278.2120533 7.067 0.008 120 1.0% FCI-XL 0.5% CI-1A 316.5434918 8.040 0.009 120 1.5% FCI-XL 0.75% CI-1A 250.6558119 6.367 0.007 90 0.4% FCI-XL 0.2% CI-1A 960.0523872 24.385 0.027 120 0.75% FCI-XL 0.5% CI-1A 279.4485513 7.098 0.008 120 1.0% FCI-XL 0.25% CI-1A 275.032487 6.986 0.008

TABLE-US-00030 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 Coupon Temp (°C) Corrosion Package Surface area (cm2) Mils/yr Mm/year Lb/ft2 Pit index L80 90 0.5% FCI-XL 0.2% CI-1A 30.199 312.8712635 7.947 0.009 2 N80 90 0.5% FCI-XL 0.2% CI-1A 30.199 202.6882721 5.148 0.006 3 J55 90 0.5% FCI-XL 0.2% CI-1A 28.922 215.1775522 5.466 0.006 0 P110 90 0.5% FCI-XL 0.2% CI-1A 28.922 308.2273045 7.829 0.009 0 QT-900 90 0.5% FCI-XL 0.2% CI-1A 34.31 143.8728277 3.654 0.004 1 1018CS 90 0.5% FCI-XL 0.2% CI-1A 37.712 499.530509 12.688 0.014 2 L80 120 1.0% FCI-XL 0.25% CI-1A 30.199 985.3507518 25.028 0.028 6 N80 120 1.0% FCI-XL 0.25% CI-1A 30.199 629.3749334 15.986 0.018 7 J55 120 1.0% FCI-XL 0.25% CI-1A 28.922 356.0164436 9.043 0.010 1 P110 120 1.0% FCI-XL 0.25% CI-1A 28.922 614.9374935 15.619 0.017 1 QT-900 120 1.0% FCI-XL 0.25% CI-1A 34.31 600.8555574 15.262 0.017 2 1018CS 120 1.0% FCI-XL 0.25% CI-1A 37.712 776.2502436 19.717 0.022 1 N80 80 1.5% FCI-XM (w/ 6-3*) 1.0% CI-1A 30.199 311.418301 7.910 0.009 N80 80 1.5% FCI-XM (w/ 6-3*) 30.199 501.2720708 12.732 0.014

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.

TABLE-US-00031 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 °C Corrosion Package Initial wt. (g) Final wt. (g) Loss wt. (g) Run time (hours) Mils/yr mm/year lb/ft2 Pit Index 90 3.0% FCI-XM 3.0% CI-1A 4.5062 4.4855 0.021 6 178.7239111 4.540 0.005 90 5.0% FCI-XM 5.0% CI-1A 4.5087 4.4888 0.020 6 171.8167068 4.364 0.005 110 3.0% FCI-XM 3.0% CI-1A 4.4348 4.3916 0.043 6 372.9890318 9.474 0.010 110 5.0% FCI-XM 5.0% CI-1A 4.4964 4.4538 0.043 6 367.8086286 9.342 0.010 90 2.5% FCI-XM 2.0% CI-1A 4.5042 4.4814 0.023 6 196.8553223 5.000 0.006 N 90 2.5% FCI-XM 2.5% CI-1A 4.4481 4.4267 0.021 6 184.7677148 4.693 0.005 N 110 2.5% FCI-XM 2.5% CI-1A 4.4813 4.4334 0.048 6 413.568857 10.505 0.012 N 110 3.0% FCI-XM 3.0% CI-1A 4.4714 4.4397 0.032 6 273.6979701 6.952 0.008 N 110 2.5% FCI-XM 2.5% CI-1A 4.5117 4.4957 0.016 5 165.772903 4.211 0.004 N 110 3.0% FCI-XM 3.0% CI-1A 4.4393 4.4127 0.027 5 275.5974513 7.000 0.006 N

[0098] 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.

[0099] 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

[0100] 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.

[0101] 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).

[0102] 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.