Organic acid systems

Abstract

An organic acid composition for use in oil industry activities, said composition comprising an arylsulfonic acid in water as well as the use of said composition to perform various operations in the oil industry. There is also disclosed a solid acid composition comprising a corrosion inhibitor ready for dissolution and use.

Claims

1. A composition for use in oil industry activities, comprising an arylsulfonic acid in water and a corrosion inhibitor composition comprising: a terpene; a propargyl alcohol or a derivative thereof; at least one amphoteric surfactant; and a solvent.

2. The composition of claim 1, wherein the arylsulfonic acid is toluenesulfonic acid.

3. The composition of claim 1, further comprising a metal iodide or iodate.

4. The composition according to claim 1, further comprising a metal iodide present in a concentration ranging from 100 to 5000 ppm.

5. The composition according to claim 1, further comprising a metal iodide present in a concentration of 1000 ppm.

6. The composition according to claim 1, wherein the arylsulfonic acid is present in a concentration ranging from 1 to 99 wt %.

7. The composition according to claim 1, wherein the arylsulfonic acid is present in a concentration ranging from 1 to 50 wt %.

8. The composition according to claim 1, wherein the arylsulfonic acid is present in a concentration ranging from 10 to 40 wt %.

9. A method to prepare a solid form organic acid-inhibitor composition for use in oil industry activities, comprising: providing an arylsulfonic acid in solid form; providing a liquid corrosion inhibitor composition; applying the liquid corrosion inhibitor composition on the arylsulfonic acid to form a mixture; and drying the mixture to produce the solid form organic acid-inhibitor composition.

10. The method according to claim 9, wherein said arylsulfonic acid is toluenesulfonic acid.

11. The method according to claim 9, wherein the liquid corrosion inhibitor composition comprises: a terpene; a propargyl alcohol or a derivative thereof; at least one amphoteric surfactant; and a solvent.

12. The method according to claim 9, wherein the at least one corrosion inhibitor component is selected from the group consisting of: a terpene; a propargyl alcohol or a derivative thereof; at least one amphoteric surfactant; and a combination thereof.

13. A solid form organic acid composition for use in oil industry activities, comprising an arylsulfonic acid and a corrosion inhibitor component.

14. The solid form organic acid composition according to claim 13, wherein the corrosion inhibitor component is selected from the group consisting of: a terpene; a propargyl alcohol or a derivative thereof; at least one amphoteric surfactant; and a combination thereof.

Description

BRIEF DESCRIPTION OF THE FIGURES

(1) The invention may be more completely understood in consideration of the following description of various embodiments of the invention in connection with the accompanying figures, in which:

(2) FIG. 1 is a graphical depiction of acid spending over time for various acid compositions;

(3) FIG. 2 contains a picture of the surface of 6 metal coupons (identified as B622, A742, A378, A704, B623 and A830) after exposure to acidic fluids as described in the description; and

(4) FIG. 3 contains a picture of the surface of 4 metal coupons (identified as A379, A706, A011 and A010) after exposure to acidic fluids as described in the description;

DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS

(5) It will be appreciated that numerous specific details have provided for a thorough understanding of the exemplary embodiments described herein. However, it will be understood by those of ordinary skill in the art that the embodiments described herein may be practiced without these specific details. In other instances, well-known methods, procedures and components have not been described in detail so as not to obscure the embodiments described herein. Furthermore, this description is not to be considered so that it may limit the scope of the embodiments described herein in any way, but rather as merely describing the implementation of the various embodiments described herein.

(6) The description that follows, and the embodiments described therein, are 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.

(7) Preferably the weight/volume % of the metal iodide or iodate in the acidic composition ranges from 0.01 to 1.5%. More preferably, the wt/vol. % of the metal iodide or iodate in the acidic composition ranges from 0.25 to 1.25%. Even more preferably, the wt/vol. % of the metal iodide or iodate liquid blends (with 10% iodide content) in the acidic composition is approximately 1%. Preferably, the metal iodide or iodate selected from the group consisting of: cuprous iodide; potassium iodide; sodium iodide; lithium iodide and combinations thereof. More preferably, the metal iodide is potassium iodide.

(8) According to another aspect of the present invention, there is provided a use of an organic acid comprising an arylsulfonic acid according to a preferred embodiment of the present invention in the oil and gas industry to perform an activity 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, nozzles, ports, jets etc.; solubilizing limestone, dolomite, and calcite; and removing undesirable scale from the group consisting of: equipment, cyclical steam wells, steam flood wells, SAGD (steam assisted gravity drainage) wells, unassisted or natural high formation temperature production wells, injection wells and their related surface and down-hole equipment and facilities at high temperatures.

(9) One of the advantages of a preferred embodiment of the present invention is the ability to blend a corrosion inhibition package with the solid form of the acid. Doing so allows one to obtain the right CI loading for the acid all the while having a solid mixture which can be transported on site and mixed thereafter with the appropriate amount of water to obtain the desired strength. This is desirable as shipping costs are reduced and dilution of the solid acid can also permit to minimize risk associated with the handling and shipping of liquid acids.

(10) Alcohols and derivatives thereof, such as alkyne alcohols and derivatives and more preferably 2-Propyn-1-ol complexed with methyloxirane can be used as corrosion inhibitors. Propargyl alcohol itself is traditionally used as a corrosion inhibitor which works extremely well at low concentrations. It is however a very toxic/flammable chemical to handle as a concentrate, so care must be taken while handling the concentrate. In the composition according to the present invention, 2-Propyn-1-ol complexed with methyloxirane is utilized where the toxic effect does not negatively impact the safety of the composition. There are derivatives of propargyl alcohol available in the industry now that are considered safe to handle, non-regulated, and approved for use in North Sea Offshore Oilfield applications. This is the preferred chemistry for the present composition. Preferably, the alkynyl alcohol or derivative thereof is present in a concentration ranging from 0.05 to 1.0% w/w. More preferably, the alkynyl alcohol or derivative thereof is present in a concentration of 0.25% w/w.

(11) Metal iodides or iodates such as potassium iodide, sodium iodide, cuprous iodide, and lithium iodide can potentially be used as a corrosion inhibitor intensifier. In fact, potassium iodide is a metal iodide traditionally used as corrosion inhibitor intensifier, however it is expensive, but works extremely well. It is non-regulated, friendly to handle, and listed on the offshore PLONOR (Pose Little Or NO Risk) list as safe chemicals to the environment. According to a preferred embodiment of the present invention, the metal iodide or iodate is cuprous iodide. According to another preferred embodiment, the metal iodide or iodate is potassium iodide. According to another preferred embodiment, the metal iodide or iodate is sodium iodide. According to yet another preferred embodiment, the metal iodide or iodate is lithium iodide. According to a preferred embodiment of the present invention, the metal iodide is present in a concentration ranging from 100 to 5000 ppm. Preferably, the metal iodide is present in a concentration of 1000 ppm.

(12) Preferably, according to a preferred embodiment of the present invention, there is provided a method to dry blend an acid with at least one corrosion inhibitor component so as to avoid having to blend such when dissolving said acid, presumably immediately prior to its use on site.

Example 1

(13) Formulation and Process to Prepare a Composition According to a Preferred Embodiment of the Invention

(14) To prepare a composition according to a preferred embodiment of the present invention containing a 50 wt % p-TSA, one first weighs out 150 g of solid p-TSA into a beaker or flask. Then the solid is diluted with water up to a 250 ml mark. Start by combining the toluenesulfonic acid with the water and mix thoroughly for a few minutes until the solid is fully dissolved. Subsequently, if desired the additives can be added. For example, according to one embodiment, one adds 2-Propyn-1-ol, complexed with methyloxirane, and potassium iodide. Circulation is maintained until all products have been solubilized. Table 1 lists the components of the composition of Example 1, including their weight percentage as compared to the total weight of the composition and the CAS numbers of each component.

(15) Similarly, to prepare a 30 wt % p-TSA composition, one takes 75 g solid p-TSA and places it in a beaker and then dilutes up to 250 mL with water. To make 1000 mL of a 50 wt % p-TSA composition one weighs 500 g of solid p-TSA and adds 620 ml of water. To make 1000 mL of a 30 wt % p-TSA composition, one weighs 300 g of solid p-TSA and adds 768 mL or water.

(16) TABLE-US-00001 TABLE 1 Composition of an acid composition according to a preferred embodiment of the present invention 30 Wt % 50 Wt % Chemical Composition Composition Water 72% 55% p-Toluenesulfonic Acid 28% 45%

(17) The resulting composition of Example 1 is a clear, odourless liquid having shelf-life of greater than 1 year. At 30 wt %, it has a specific gravity of 1.083±0.02. At 50 wt %, it has a specific gravity of 1.132±0.02. It is completely soluble in water and its pH is less than 1.

(18) TABLE-US-00002 TABLE 2 Composition of a known acid composition used as a comparator % Wt Chemical Composition Water 57.65%  Methanesulfonic Acid   42% 2-Propyn-1-ol, complexed with 0.25% methyloxirane Potassium Iodide 0.01%
Solubility Testing

(19) To evaluate the solubilizing strength of preferred compositions according to the present invention, various strength compositions were tested at various temperatures on calcium carbonate and dolomite. The results are set out in Tables 3 (on calcium carbonate) and 4 (on dolomite).

(20) TABLE-US-00003 TABLE 3 Results of the Acid Solubility test on Calcium Carbonate using a 30% or 50% p-TSA composition according to Example 1 Total Temp/ Acid Initial Final Weight Solubility - Fluid ° C. Volume/ml Weight Weight Loss/g kg/m.sup.3 50% p-TSA 20 50 10.0 5.1 4.9 98.0 50% p-TSA 55 50 10.0 4.7 5.3 106.0 50% p-TSA 90 50 10.0 4.6 5.4 108.0 30% p-TSA 20 50 10.0 7.17 2.8 56.0 30% p-TSA 20 100 10.0 2.1 7.9 79.0

(21) TABLE-US-00004 TABLE 4 Results of testing for the solubility of dolomite using a 30% or 50% p-TSA composition according to Example 1 Total Temp/ Acid Initial Final Weight Solubility - Fluid ° C. Volume/ml Weight Weight Loss/g kg/m.sup.3 50% p-TSA 20 50 10.0204 9.9752 0.0452 0.9 30% p-TSA 20 50 10.0037 10.0355 −0.0318 0.0
Metal Scale Solubilizing Testing

(22) To evaluate the metal solubilizing strength of preferred compositions according to the present invention, various strength compositions were tested at a temperature of 20° C. to determine their solubilizing strength on iron sulfide and zinc sulfide. Both metal sulfide represent possible scales found inside well bores during oil and gas operations. The ability of an acid to dissolve such scale will greatly contribute to minimizing well shut downs from reduced flow due to scaling issues. The solubility results are set out in Tables 5 (iron sulfide) and 6 (zinc sulfide).

(23) TABLE-US-00005 TABLE 5 Acid solubility test results using a 30% or 50% p-TSA composition according to Example 1 with iron sulfide Total Temperature/ Acid Initial Final Weight Solubility - Fluid ° C. Volume/ml Weight Weight Loss/g kg/m.sup.3 50% p-TSA 20 50 10.0242 11.7331 −1.7089 0.0 30% p-TSA 20 50 10.0007 5.2489 4.7518 95.0

(24) TABLE-US-00006 TABLE 6 Acid solubility test results using a 30% or 50% p-TSA composition according to Example 1 with zinc sulfide Total Temperature/ Acid Initial Final Weight Solubility - Fluid ° C. Volume/ml Weight Weight Loss/g kg/m.sup.3 50% p-TSA 20 50 3.0409 2.7214 0.3195 6.4 30% p-TSA 20 50 5.0035 11.3276 −6.3241 0.0
Corrosion Testing

(25) Compositions according to the present invention were exposed to corrosion testing. Various steel grades were exposed to compositions according to the present invention for various exposure duration and temperatures. Depending on the intended use/application of an acidic fluid composition comprising a corrosion inhibitor package, 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. Where applicable the fluids (acid compositions) were diluted as indicated.

(26) TABLE-US-00007 TABLE 7 Corrosion results on various metals exposed to a 50% p-TSA composition comprising various corrosion inhibitor packages (steel density = 7.86 g/cc) (at 90° C. and a pressure of 0 psi) Total Surface Steel Duration CI wt loss area Density Mils/ Mm/ Lb/ type (hour) package (g) (cm.sup.2) (g/cc) year year ft.sup.2 J55 6 0.5% CI-5, 0.1191 30.129 7.86 289.083 7.343 0.008 0.25% CI- 1A, 0.1% NE-1 N80 6 0.5% CI-5, 0.2605 31.806 7.86 598.948 15.213 0.017 0.25% CI- 1A, 0.1% NE-1 QT-800 6 0.5% CI-5, 0.2916 30.129 7.86 707.781 17.978 0.020 0.25% CI- 1A, 0.1% NE-1 QT-100 6 0.5% CI-5, 0.2114 30.129 7.86 513.117 13.033 0.014 0.25% CI- 1A, 0.1% NE-1 CI-1A refers to a 10% potassium iodide solution; CI-5 refers to a proprietary corrosion inhibitor package comprising a terpene; a cinnamaldehyde or a derivative thereof; at least one amphoteric surfactant; and a solvent.

(27) TABLE-US-00008 TABLE 8 Corrosion results on various metals exposed to a 30% p-TSA composition comprising various corrosion inhibitor packages (steel density = 7.86 g/cc) (at 90° C. and a pressure of 0 psi) Total Surface Steel Duration CI wt loss area Density Mils/ Mm/ Lb/ type (hour) package (g) (cm.sup.2) (g/cc) year year ft.sup.2 J55 6 1% CI- 0.0806 30.129 7.86 195.635 4.969 0.005 5CNE N80 6 1% CI- 0.2955 31.806 7.86 679.421 17.257 0.019 5CNE QT-800 6 1% CI- 0.1599 30.129 7.86 388.115 9.858 0.011 5CNE QT-100 6 1% CI- 0.1314 30.129 7.86 318.938 8.101 0.009 5CNE QT-900ss 6 1% CI- 0.0808 16.632 7.86 355.269 9.024 0.010 5CNE (1 day aging) CI-5CNE refers to a 10% potassium iodide solution, a proprietary corrosion inhibitor package comprising a terpene; a cinnamaldehyde or a derivative thereof; at least one amphoteric surfactant; and a solvent.

(28) TABLE-US-00009 TABLE 9 Corrosion results on various metals exposed to a 50% p-TSA composition comprising various corrosion inhibitor packages (steel density = 7.86 g/cc) (at 55° C. and at a pressure of 0 psi) Total Surface Steel Duration CI wt loss area Density Mils/ Mm/ Lb/ type (hour) package (g) (cm.sup.2) (g/cc) year year ft.sup.2 1018CS 168 0.5% CI-5, 0.1112 34.710 7.86 8.367 0.213 0.007 0.25% CI- 1A, 0.1% NE-1 A7075 168 0.5% CI-5, 0.7622 32.064 2.81 173.660 4.411 0.049 0.25% CI- 1A, 0.1% NE-1 CI-1A refers to a 10% potassium iodide solution; CI-5 refers to a proprietary corrosion inhibitor package comprising a terpene; a cinnamaldehyde or a derivative thereof; at least one amphoteric surfactant; and a solvent.

(29) TABLE-US-00010 TABLE 10 Corrosion results on various metals exposed to a 30% p-TSA composition comprising various corrosion inhibitor packages (steel density = 7.86 g/cc)(at 55° C. and at a pressure of 0 psi) Total Surface Steel Duration CI wt loss area Density Mils/ Mm/ Lb/ type (hour) package (g) (cm.sup.2) (g/cc) year year ft.sup.2 1018CS 168 1% CI- 0.2346 34.710 7.86 17.653 0.448 0.014 5CNE A7075 168 1% CI- 0.0533 32.064 2.81 12.144 0.308 0.003 5CNE CI-5CNE refers to a 10% potassium iodide solution, a proprietary corrosion inhibitor package comprising a terpene; a cinnamaldehyde or a derivative thereof; at least one amphoteric surfactant; and a solvent.

(30) TABLE-US-00011 TABLE 11 Corrosion results on various metals exposed to a 50% p-TSA composition comprising various corrosion inhibitor packages (steel density = 7.86 g/cc) (at a pressure of 400 psi) for a duration of exposure of 6 hours Total Surface Steel Temp CI wt loss area Mils/ Mm/ Lb/ type (° C.) package (g) (cm.sup.2) year year ft.sup.2 J55 130 1.75% CI- 0.1647 30.129 399.765 10.154 0.011 5, 1.5% CI-1A, 0.1% NE-1 N80 130 1.75% CI- 0.2933 31.806 674.363 17.129 0.019 5, 1.5% CI-1A, 0.1% NE-1 QT-800 130 1.75% CI- 0.4422 30.129 1073.322 27.262 0.030 5, 1.5% CI-1A, 0.1% NE-1 QT-100 130 1.75% CI- 0.2682 30.129 650.984 16.535 0.018 5, 1.5% CI-1A, 0.1% NE-1

(31) TABLE-US-00012 TABLE 12 Corrosion results on various metals exposed to a 30% p-TSA composition comprising various corrosion inhibitor packages (steel density = 7.86 g/cc for all steels other than super duplex with a density of 7.5g/cc) (at a pressure of 400 psi) for a duration of exposure of 6 hours Total Surface Steel Temp CI wt loss area Mils/ Mm/ Lb/ type (° C.) package (g) (cm.sup.2) year year ft.sup.2 J55 130 1% CI- 0.1140 30.129 276.705 7.028 0.008 5CNE N80 130 1.75% CI- 0.1532 31.806 352.241 8.947 0.010 5, 1.5% CI-1A, 0.1% NE-1 QT-800 130 1.75% CI- 0.1970 30.129 478.165 12.145 0.013 5, 1.5% CI-1A, 0.1% NE-l QT-100 130 1% CI- 0.1098 30.129 266.510 6.769 0.007 5CNE P110 130 2% CI- 0.0964 34.839 202.354 5.140 0.006 5CNE Super 130 2% CI- 0.0293 34.710 62.609 1.590 0.002 Duplex 5CNE 2507

(32) TABLE-US-00013 TABLE 13 Corrosion results on various metals exposed to a 50% p- TSA composition comprising various corrosion inhibitor packages (steel density = 7.86 g/cc) (at a pressure of 0 psi and a temperature 90° C.) with a duration exposure of 6 hours and a coupon surface are of 34.710 cm.sup.2 Steel CI Wt loss Density type package (g) (g/cm.sup.2) Mils/year Mm/year Lb/ft.sup.2 Super 0.75% CI- 0.0045 7.75 9.616 0.244 0.000 duplex 5, 0.5% CI- 2507 1A, 0.1% NE-1 duplex 0.75% CI- 0.0247 7.70 53.122 1.349 0.001 2205 5, 0.5% CI- 1A, 0.1% NE-1

(33) TABLE-US-00014 TABLE 14 Corrosion results on various metals exposed to a 50% p-TSA (dry acid) composition comprising various corrosion inhibitor packages (steel density = 7.86 g/cc) (at a pressure of 400 psi and a temperature 150° C.) with a duration exposure of 6 hours Surface Steel CI Wt loss area type package (g) (cm.sup.2) Mils/year Mm/year Lb/ft.sup.2 N80 1% CI- 0.2064 31.806 474.560 12.054 0.013 QT-800 1% CI- 0.2104 30.129 510.690 12.972 0.014

(34) With respect to the corrosion impact of the composition on typical oilfield grade steel, it was established that it was clearly well below the acceptable corrosion limits set by industry for various applications.

(35) Corrosion Aging Testing

(36) Additional corrosion testing was carried out to investigate the effect of aging the toluenesulfonic acid in solid form after the application of a liquid corrosion inhibitor composition onto the acid and the corrosiveness of various compositions according to preferred embodiments of the present invention. The results are listed in Tables 15 and 16. This is to examine the product shelf life and the results indicate that the compositions have excellent properties in terms of steel protection.

(37) TABLE-US-00015 TABLE 15 Corrosion results (in lb/ft.sup.2) on N80 metal exposed to a 30% p-TSA or 50% p-TSA composition at various temperature and days of aging corrosion inhibitor package in dry acid prior to dilution with water 30% p-TSA 30% p-TSA 50% p-TSA 50% p-TSA Days Coupon 90° C. 150° C. 90° C. 150° C. 1 N80 0.019 0.028 0.010 0.016 5 N80 0.017 0.047 0.005 0.014 14 N80 0.015 0.034 0.007 0.009 60 N80 0.010 0.023 0.006 0.014

(38) TABLE-US-00016 TABLE 16 Corrosion results (in lb/ft.sup.2) on QT-900 metal exposed to a 30% p-TSA or 50% p-TSA composition at various temperature and days of aging corrosion inhibitor package in dry acid prior to dilution with water 30% p-TSA 30% p-TSA 50% p-TSA 50% p-TSA Days Coupon 90° C. 150° C. 90° C. 150° C. 1 QT-900 0.008 0.013 0.006 0.013 5 QT-900 0.008 0.015 0.005 0.009 14 QT-900 0.008 0.019 0.005 0.006 60 QT-900 0.007 0.024 0.006 0.008

(39) TABLE-US-00017 TABLE 17 Corrosion results on various metals exposed to a 50% p-TSA composition at various temperature for a 6 hour exposure time Temp Corrosion (° C.) Coupon Serial# (lb/ft.sup.2) Observations 90 J55 B622 0.008 No Pits 90 N80 A742 0.007 No Pits 90 QT-800 A378 0.008 No Pits 90 QT-100 A704 0.007 No Pits 130  J55 B623 0.011 No Pits 130  N80 A830 0.019 No Pits 130  QT-800 A379 0.030 Pits 130  QT-100 A706 0.018 Pits 90 Super Duplex 2507 A011 0 No pits 90 Duplex 2205 A010 0.001 No pits 150  N80 A838 0.013 No pits 150  QT-800 A376 0.014 No pits 150* QT-900 C266 0.013 No pits  130** J55 C115 0.008 No pits  150*** N80 A941 0.019 No pits *refers to an experiment conducted with a 50% TSA concentration (with 1% CI-5CNE aged for a day) *refers to an experiment conducted with a 30% TSA concentration (with 1% CI-5CNE) *refers to an experiment conducted with a 30% TSA concentration (with 1% CI-5CNE aged for 387 days)

(40) With respect to the corrosion impact of the composition on typical oilfield grade steel, it was established that it was clearly well below the acceptable corrosion limits set by industry for certain applications, such as spearhead applications or downhole scaling. Moreover, it was noted, upon visual inspection of the various coupons, that the p-TSA 50 wt % composition performed well in the prevention of pitting corrosion (see coupons photographs in FIGS. 2 and 3) on most metals at all temperature tested. Visual analysis of the coupons confirms that the compositions according to a preferred embodiment of the present invention preferable pitting corrosion profile when considering that pitting corrosion is the predominant problem in the use of alkylsulfonic acids such as methanesulfonic acid.

(41) Elastomer Testing

(42) When common sealing elements used in the oil and gas industry come in contact with acid compositions they tend to degrade or at least show signs of damage. A number of sealing elements common to the industry were exposed to a composition according to a preferred embodiment of the present invention to evaluate the impact of the latter on their integrity. More specifically, the hardening and drying and the loss of mechanical integrity of sealing elements can have substantial consequences to the operations of wells and result in undesirable shut downs to replace defective sealing elements. Testing was carried out to assess the impact of the exposure of composition of Example 1 to various elastomers. Long term (72-hour exposure) elastomer testing on the composition of Example 1 (at 50% dilution) at 70° C. showed little to no degradation of various elastomers, including Nitrile 70, Viton 75, and EPDM 70 style sealing elements.

(43) TABLE-US-00018 TABLE 18 Elastomer Testing - Exposure of a composition according to the present invention (50% concentration) for 3 days @ 70° C. Weight Weight Weight Thickness Thickness Thickness Elastomer before/g after/g Change/g before/mm after/mm Change/mm Viton V75 0.3447 0.3479 −0.0032 3.54 3.56 −0.02 240 Nitrile N70 0.2468 0.2722 −0.0254 3.43 3.60 −0.17 240 EPDM E70 0.1203 0.1255 −0.0052 2.57 2.61 −0.04 126

(44) TABLE-US-00019 TABLE 19 Elastomer Testing - Exposure of a composition according to the present invention (50% concentration) for 3 days @ 20° C. Weight Weight Weight Thickness Thickness Thickness Elastomer before/g after/g Change/g before/mm after/mm Change/mm Viton V75 0.3487 0.349 −0.0003 3.53 3.53 0.00 240 Nitrile N70 0.2497 0.2516 −0.0019 3.40 3.46 −0.06 240 EPDM E70 0.135 0.1353 −0.0003 2.63 2.63 0.00 126

(45) TABLE-US-00020 TABLE 20 Elastomer Testing - Exposure of a composition according to the present invention (100% concentration) for 28 days @ 20° C. Weight Weight Weight Thickness Thickness Thickness Elastomer before/g after/g Change/g before/mm after/mm Change/mm Viton V75 0.3268 0.328 −0.0012 3.49 3.55 −0.06 240 Nitrile N70 0.2482 0.2545 −0.0063 3.49 3.53 −0.04 240 EPDM E70 0.1232 0.1265 −0.0033 2.54 2.59 −0.05 126

(46) TABLE-US-00021 TABLE 21 Elastomer Testing - Exposure of a composition according to the present invention (30% concentration) for 3 days @ 70° C. Weight Weight Weight Thickness Thickness Thickness Elastomer before/g after/g Change/g before/mm after/mm Change/mm Viton V75 0.3312 0.3371 −0.0059 3.57 3.58 −0.01 240 Nitrile N70 0.2276 0.2604 −0.0328 3.52 3.63 −0.11 240 EPDM E70 0.1023 0.1092 −0.0069 2.60 2.64 −0.04 126

(47) TABLE-US-00022 TABLE 22 Elastomer Testing - Exposure of a composition according to the present invention (30% concentration) for 3 days @ 20° C. Weight Weight Weight Thickness Thickness Thickness Elastomer before/g after/g Change/g before/mm after/mm Change/mm Viton V75 0.3307 0.3311 −0.0004 3.55 3.49 0.06 240 Nitrile N70 0.2307 0.2325 −0.0018 3.46 3.49 −0.03 240 EPDM E70 0.0995 0.1003 −0.0008 2.57 2.60 −0.03 126

(48) TABLE-US-00023 TABLE 23 Elastomer Testing - Exposure of a composition according to the present invention (30% concentration) for 28 days @ 20° C. Weight Weight Weight Thickness Thickness Thickness Elastomer before/g after/g Change/g before/mm after/mm Change/mm Viton V75 0.3525 0.3543 −0.0018 3.51 3.46 0.05 240 Nitrile N70 0.2239 0.2344 −0.0105 3.49 3.50 −0.01 240 EPDM E70 0.0882 0.0930 −0.0048 2.60 2.56 0.04 126

(49) The uses (or applications) of the compositions according to the present invention upon dilution thereof ranging from approximately 1 to 75% dilution are listed in Table below, include, but are not limited to: injection/disposal in wells; squeezes and soaks or bullheads; acid fracturing, acid washes or matrix stimulations; fracturing spearheads (breakdowns); pipeline scale treatments; cement breakdowns or perforation cleaning; pH control; and de-scaling applications.

(50) TABLE-US-00024 TABLE 24 Various uses and suggested dilutions of the composition according to a preferred embodiment of the present invention Suggested Application Dilution Benefits Injection/ 50% Compatible with mutual solvents and Disposal solvent blends, very cost effective. Wells Squeezes & 33%-50% Ease of storage & handling, cost effective Soaks compared to conventional acid Bullhead stimulations. Ability to leave pump Annular equipment in wellbore. Acid Fracs 50%-66% Decreased shipping and storage compared to conventional acid, no blend separation issues, comprehensive spend rate encourages deeper formation penetration. Frac 33%-66% Able to adjust concentrations on the fly. Spearheads Decreased shipping and storage on (Break-downs) location. Cement 50% Higher concentrations recommended due Break-downs to lower temperatures, and reduced solubility of aged cement. pH Control 0.1%-1.0% Used in a variety of applications to adjust pH level of water based systems. Liner 1%-5% Continuous injection/de-scaling of slotted De-Scaling, liners, typically at very high temperatures. Heavy Oil

(51) 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.