MONOVALENT BRINES WITH HIGH DENSITY AND LOW TCT AND THEIR USES.

Abstract

A method is provided for using a suppression factor fluid during well activity. The method comprises the steps of introducing a suppression factor fluid into a well, wherein the suppression factor fluid comprises an untreated monovalent brine and a suppression sugar alcohol, the suppression sugar alcohol being in an operative quantity to achieve a suppression factor, wherein the suppression factor fluid has an upper density limit that is greater than the upper density limit of the monovalent brine; and completing the well activity in the well, such that the suppression sugar alcohol inhibits crystallization during the well activity.

Description

HIGH-DENSITY MONOVALENT BRINES And low TCT and its uses BACKGROUND Related Patent Application This patent application claims priority from U.S. Provisional Patent Application No. 62 / 312,876, filed on March 24, 2016. For purposes of U.S. patent practice, this patent application incorporates the contents of the provisional patent application by reference in their entirety. Technical field Compositions for use as well fluids are described. More specifically, compositions with low true crystallization temperatures and high densities for use as well fluids are described. Description of related art When used as a heavy completion fluid, brines can crystallize if exposed to lower temperatures or higher pressures. As the density of a brine increases above its eutectic point, so do the true crystallization temperature (TCT) and the pressure crystallization temperature (PCT), which can lead to the blockage of well tubulars above the surface if the fluid crystallizes. Applying pressure to a brine at a density above the eutectic point results in an increase in density, which in turn can lead to crystallization. Crystallization inhibitors can be used to decrease TCT and PCT, but this can also lead to a reduction in brine density. Zinc, such as zinc bromide (ZnBr2), can be added to increase density. However, zinc is a marine pollutant and can cause problems during processing if residual zinc is present in the crude oil sent to the refinery. In conventional brine systems, typical crystallization inhibitors such as methanol and ethylene glycol can lower the total crystallization temperature (TCT), but they can also dramatically decrease the brine density (making it unsuitable for the original purpose). This means that more solid monovalent salt must be added to restore the brine density to the operating density. In most cases, sufficient monovalent salt cannot be added to achieve the required operating density and crystallization temperature without adding weighting agents such as zinc bromide. Summary of the invention Compositions for use as well fluids are described. More specifically, compositions with low true crystallization temperatures and high densities for use as well fluids are described. In the first aspect, a method is provided for using a suppression factor fluid during well work. The method includes the steps of introducing a suppression factor fluid into a well. The suppression factor fluid comprises untreated monovalent brine and a suppression sugar alcohol. The suppression sugar alcohol is in an operable quantity to achieve a suppression factor of at least 0.1, where the upper density limit of the suppression factor fluid is greater than the upper density limit of the untreated monovalent brine. The method further includes the step of terminating the well work in such a way that the suppression sugar alcohol inhibits crystallization during the well work. In certain respects, the untreated monovalent brine is selected from the group consisting of sodium bromide-based brine, sodium chloride-based brine, sodium formate-based brine, potassium bromide-based brine, potassium chloride-based brine, potassium formate-based brine, lithium bromide-based brine, lithium chloride-based brine, cesium formate-based brine, and combinations thereof. In certain respects, the suppression sugar alcohol is selected from the group consisting of sorbitol, xylitol, and combinations thereof. In certain respects, the suppression factor is in the range of 0.1 to 10. In a second aspect, a composition is provided for use as a suppression factor fluid. The composition includes an untreated monovalent brine and a suppression sugar alcohol. The suppression sugar alcohol is in an operable amount to achieve a suppression factor of at least 0.1, wherein the suppression factor fluid has an upper density limit that is greater than the upper density limit of the monovalent brine. In certain aspects, the composition does not contain cesium. In a third aspect, a composition is provided for use as a suppression factor fluid. The composition includes from 50% to 99.9% by weight of an untreated monovalent brine and from 0.1% to 50% by weight on a dry weight basis of a suppression sugar alcohol. In a fourth aspect, a method for creating a suppression factor fluid is provided. The method includes the steps of adding a quantity of a suppression sugar alcohol to a monovalent brine to create a mixture, where the quantity of the suppression sugar alcohol is operable to achieve a suppression factor of between 0.1 and 10, and mixing the mixture until the suppression sugar alcohol is dissolved. In certain aspects, the amount of suppressant sugar alcohol is between 0.1% and 50% by weight on a dry weight basis. In certain embodiments, the suppressant sugar alcohol is added in solid form. In certain aspects, the suppressant sugar alcohol is added in aqueous form. In certain aspects, the method further comprises adding another monovalent salt to the suppressant factor fluid after the suppressant sugar alcohol, following the mixing step, such that the other monovalent salt achieves an operating density of the suppressant factor fluid. Detailed Description of the Invention Although the scope is described with several embodiments, it is understood that a person skilled in the relevant art will appreciate that many examples, variations, and alterations to the apparatus and methods described herein fall within the scope and spirit. Accordingly, the examples of embodiments described herein are presented without any loss of generality and without imposing limitations. Implementations of a suppression factor fluid may include a monovalent brine and a suppression sugar alcohol and methods for using the suppression factor fluid as a well fluid during a well activity. As used herein, crystallization refers to the formation of crystals in a brine solution upon cooling. Without adhering to any particular theory, crystallization occurs when it is thermodynamically favorable, meaning it takes less energy to crystallize than to remain in solution. In other words, the driving force for crystallization is when the free energy of the initial solution is greater than the sum of the free energies of the crystalline phase and the final solution. As an example, crystallization in a well can occur in the mudline due to mudline temperatures. As used herein, well fluid refers to a fluid that can be used in a well. Well fluids include drilling fluids, completion fluids, packing fluids, production fluids, fracturing fluids, and similar fluids used in well activities. As used herein, well activity refers to drilling activities, production activities, and completion activities. Some examples of well activities include, but are not limited to, drilling, completion, and alteration. As used herein, stable or stabilize means that when a composition, component, or compound is stable, the composition, component, or compound does not degrade, decompose, or precipitate out of solution. As used herein, the true crystallization temperature (TCT) refers to the temperature at which crystals form in a brine for a given brine density. The TCT is defined as the temperature corresponding to the maximum temperature reached after the minimum supercooling. On a temperature chart during a cooling cycle, the TCT is the maximum temperature reached after the minimum supercooling or the inflection point in cases without any supercooling. If there is no supercooling, the TCT is equivalent to the first crystal to appear (FCTA). The TCT is the measured crystallization temperature closest to the temperature at which a brine naturally crystallizes in pumps, lines, filtration units, and tanks. It is also described in API Recommended Practice 13J, Testing of Heavy Brines, 5th Ed.October 2014 [Recommended Practice for API 13J, Testing Heavy Brines, 5th Edition, October 2014]. As an example, in an untreated monovalent brine containing only a monovalent salt and water, the total soluble concentration (TSC) changes as the brine density changes. On the salt side of a solubility curve, as density increases (in other words, as more salt is added), the TSC also increases. Conversely, on the ice side of a solubility curve, below the eutectic point, as density increases, the TSC decreases. Table 1 provides a list of TSCs and brine densities. Table 1. TCT of various brines at specific densities Brine Brine Density TCT NaBr 1.473 kg / L -2.8°C NaCl 1.198 kg / L -3.9°C KBr 1.294 kg / L -5°C KC1 1.138 kg / 1 -7.8°C NH4C1 1.066 -0.6 KHCOOH 1.581 -3.3°C As used herein, a suppression sugar alcohol refers to a component derived from the reduction of a saccharide that is useful as a suppression additive in lowering the true crystallization temperature. Examples of suitable suppression sugar alcohols include sorbitol, xylitol, and combinations thereof. Sugar alcohols do not contain sugars. Advantageously, sugar alcohols are biodegradable, exhibit low toxicity, and do not bioaccumulate. Without adhering to any particular theory, replacing some of the water in a brine solution with an alcohol can affect the thermodynamic driving force for crystal formation because the water molecules surrounding the salt ions play a significant role in the thermodynamics of phase transitions in solution. The entrapment or release of water molecules has a major effect on this thermodynamics.In at least one embodiment, the suppression sugar alcohol includes sorbitol in combination with other sugar alcohols. In at least one embodiment, the suppression sugar alcohol includes xylitol in combination with other sugar alcohols. In at least one embodiment, the suppression sugar alcohol includes xylitol and sorbitol in combination with other sugar alcohols. As used herein, the suppression factor is a measure of the reduction in TCT relative to the amount of suppressed sugar alcohol. The suppression factor is determined by the following equation: Suppression factor = (TCTSin ad deSuP - TCTad desup) / % of suppression additive (equation 1) where TCTSin ad de sup is the TCT of an untreated monovalent brine, TCTad de sup is the TCT of a monovalent brine with an added suppression additive, and % of suppression additive refers to the amount of suppression additive added to the divalent brine. As used herein, the upper density limit refers to the density that can be achieved in a brine fluid while avoiding crystallization under well conditions, including mud line temperature and pressure. Density is a measure of the monovalent salt loading in an aqueous fluid, measured in kg per liter. For a sodium bromide-based brine (a solution of only sodium bromide and water), the upper density limit is 1.497 kg / L.For a brine based on sodium chloride (a solution of only sodium chloride and water), the upper limit of density is. 1.198 kg / 1. Above the upper density limit, crystallization may occur. As used herein, operating density refers to the desired or target density of a well fluid needed for a particular well activity. As used herein, solubility refers to the measure of how much of a component can be dissolved in a fluid. As used herein, untreated monovalent brine refers to a monovalent brine that does not contain a suppression additive, where the suppression additive suppresses TCT. The embodiments provide a suppression factor fluid that has a lower TCT than untreated monovalent brine of similar density. The addition of a suppression sugar alcohol to untreated monovalent brine results in minimal density loss compared to untreated monovalent brine. Advantageously, the addition of a suppression sugar alcohol to monovalent brine can reduce the TCT of the monovalent brine for a given brine density. The embodiments can provide zinc-free suppression factor fluids with upper density limits of 1.665 kg / L and a TCT at least -16.1°C below that of untreated divalent brine of the same density.In at least one embodiment, the suppression factor fluid composition can suppress the thermodynamic event that leads to crystallization and allows more monovalent salts to be added to the solution than compositions without a suppression sugar alcohol. Suppression factor fluids are stable (do not crystallize) even when the salt content of the fluid is greater than the saturation point of the salt in water at any given temperature. Advantageously, embodiments of suppression factor fluids provide fluids with densities that expand beyond those of conventional fluids used in well operations, while suppressing TCT, thus addressing a need in the industry. A suppression factor fluid is provided for use in a well activity. The composition of the suppression factor fluid includes an untreated monovalent brine and a suppression sugar alcohol. Untreated monovalent brine can be any aqueous solution containing at least one monovalent salt with an upper density limit suitable for use in well operations. The untreated monovalent brine can be selected based on the well activity to be performed, well conditions, operating density, and upper density limit. Examples of untreated monovalent brines include sodium bromide (NaBr)-based brine, sodium chloride (NaCl)-based brine, sodium formate (HCOONa)-based brine, potassium bromide (KBr)-based brine, potassium formate (HCOOK)-based brine, lithium bromide (LiBr)-based brine, lithium chloride (LiCl)-based brine, cesium formate (HCOOCs)-based brine, and combinations thereof.Untreated monovalent brine has a true crystallization temperature related to the upper density limit. The suppression sugar alcohol is added in an operable amount to obtain a suppression factor of at least 0.1, alternatively between 0.1 and 10. In at least one embodiment, the suppression sugar alcohol is added in an operable amount to obtain a TCT suppression of at least -16.1°C. As used herein, suppression means reduction; in other embodiments, a TCT suppression is a reduction of the TCT. In at least one embodiment, the suppression sugar alcohol is added to the monovalent brine in a solid form. The solid form of a suppression sugar alcohol is free-flowing and allows for easier handling, does not require storage tanks and pumps, and can be housed in locations, including remote locations, with space restrictions. In at least one embodiment, the suppression sugar alcohol is added to the monovalent brine in an aqueous form.In at least one embodiment, the suppression sugar alcohol is added to the monovalent brine in aqueous form and is calculated on a dry weight basis. In at least one embodiment, the suppression sugar alcohol is sorbitol and can be added to the monovalent brine as an aqueous solution containing 70% by weight (dry weight basis) of sorbitol and 30% by weight of water.The amount of added suppressive sugar alcohol may be between 0.1 percent (%) by weight on a dry weight basis and 50% by weight on a dry weight basis, alternatively between 1% by weight on a dry weight basis and 50% by weight on a dry weight basis, alternatively between 10% by weight on a dry weight basis and 50% by weight on a dry weight basis, alternatively between 10% by weight on a dry weight basis and 50% by weight on a dry weight basis, alternatively between 10% by weight on a dry weight basis and 20% by weight on a dry weight basis, alternatively between 20% by weight on a dry weight basis and 30% by weight on a dry weight basis, alternatively between 30% by weight on a dry weight basis and 40% by weight on a dry weight basis, and alternatively between 40% by weight on a dry weight basis and 50% by weight on a dry weight basis. The suppression factor fluid has an upper density limit. The upper density limit may be greater than 1.557 kg / L. In at least one embodiment, the upper density limit of the suppression factor fluid is greater than 1.497 kg / L. The true crystallization temperature of the suppression factor fluid for a given upper density limit is lower than the true crystallization temperature of monovalent brine at the same upper density limit. The true crystallization temperature of the suppression factor fluid can range from -40°C to 21.1°C. In at least one embodiment, the suppression factor fluid does not contain cesium in any form. In at least one embodiment, the suppression factor fluid does not contain formate. In at least one embodiment, the suppression sugar alcohol and the suppression factor fluid do not contain glycols, including, for example, ethylene glycol and propylene glycol. The suppression factor fluid is created by adding a quantity of a suppression sugar alcohol to an untreated monovalent brine to create a mixture. The quantity of the suppression sugar alcohol is operable to achieve a suppression factor of between 0.1 and 10, and alternatively up to 10. The mixture may be stirred until the suppression sugar alcohol dissolves. As used herein, stirring or mixing includes any form of combining a liquid and a solid, such as agitation, beating, or blending, and any equipment capable of creating a mixed fluid may be used. In at least one embodiment, the density of the monovalent brine is higher than the operating density of the suppression factor fluid, such that when the suppression sugar alcohol is added, the density of the suppression factor fluid is reduced to the operating density.In at least one embodiment, another monovalent salt can be added to the suppression factor fluid after the suppression sugar alcohol is added to increase or restore the desired density. In at least one embodiment, suppression factor fluids have densities on the salt side of a solubility curve, meaning their densities are above the eutectic point. On the salt side of a solubility curve, as density increases (i.e., more salt is added), so does the total soluble concentration (TSC). Conversely, on the ice side of a solubility curve, below the eutectic point, as density increases, the TSC decreases. In at least one embodiment, the suppression sugar alcohol is sorbitol. The density of sorbitol is 1.488 kg / L. In at least one embodiment, the suppression factor fluid includes a sodium-based brine and sorbitol as the suppression sugar alcohol and has an upper density limit of 1.665 kg / L. The density of xylitol is 1.519 kg / 1. A method is provided for using suppression factor fluid during well activity. The suppression factor fluid is introduced into a well. Well activity is terminated in such a way that, during well activity, the suppression sugar alcohol inhibits crystallization. In at least one embodiment, the suppression factor fluid may include additives used in well fluids. In at least one embodiment, an additive that may be added to the suppression factor fluid includes a stabilizing compound to inhibit the degradation of the suppression sugar alcohol at downhole temperatures, where the stabilizing compound is effective in inhibiting degradation at downhole temperatures above 121.1°C.Examples of stabilizing compounds suitable for use include amine bases, such as monoethanolamine (MEA), diethanolamine (DEA), triethanolamine (TEA), ethylenediamine (EDA), diethylenetriamine (DETA), triethylenetetramine (TETA), tetraethylenepentamine (ΤΕΡΑ), pentaethylenetetramine (PETA), pentaethylenehexamine (PERA), aminoethylpiperazine (AEP), ethyleneamine E-100 (available from Huntsman Corporation), piperazine, diethylhydroxylamine (DEHA), diethylaminoethanol (DEAE), dimethylethanolamine (DMEA), methoxypropylamine (ΜΟΡΑ), morpholine, n-aminopropylmorpholine (APM),. 4-[2-hydroxyethyl]morpholine, diglycolamine, N—[3—aminopropyl]diethanolamine, aminoethylethanolamine (AEEA) and combinations thereof. Examples Example 1. A suppression factor fluid was created. To 500 g of a NaBr material solution at 1.497 kg / L, 240 g of sorbitol were added in various increments, and the results upon mixing were observed, as shown in Table 2. The final suppression factor fluid contained 30.6 wt% NaBr, 36.8 wt% water, and 32.6 wt% sorbitol. The density was 1.488 kg / L. The TCT was less than -1.1°C, and the viscosity was 10.3 cP. Table 2. Observations upon adding sorbitol to the sample of Example 1 Weight added (g) Observation % by weight 105 Agitation, no actual exotherm, began to heat up, but the solution quickly became clear 17.4 57 Became clear 24.5 33 Became clear 28.0 46 32.6 Total weight: 24g Example 2. Example 2 compared the use of different suppression additives. The untreated monovalent brine was a 1.497 kg / L sodium bromide-based brine, also used as Sample 1. Sample 2 was prepared by adding the amount of sorbitol indicated in Table 3 to the 1.497 kg / L sodium bromide-based brine, and the final density was measured. Samples 3–7 were prepared by adding the amount of suppression additive indicated in Table 3 to the 1.497 kg / L sodium bromide-based brine, and more solid sodium bromide was added to achieve the final density indicated in Table 3. The suppression factor was calculated for Sample 2 and for Sample 7. Table 3. Compositions of Samples 1-7 of Example 2 Additive Quantity Density TCT Viscosity Factor of or of of d (°C) dad Suppression final additive (cP) ion of (kg / 1) suppression (% by weight) Sample None 0 1.497 2.8 0 1st Sample 2 Sorbitol 32.6 1.488 34.4 20.3 >1.93 Sample 3 Sorbitol 45.1 1.560 -12.2 129 Not applicable Sample 4 Sorbitol 33.2 1.572 -7.6 35.8 Not applicable Sample 5 Sorbitol 31.1 1.621 15.6 45 Not applicable Sample 6 Sorbitol 39.8 1.660 13.9 384 Not applicable Sample 7 Glycerol 9.2 1.497 5.6 -0.43 A suppression factor could not be calculated for samples 2-6 because it was not possible to measure a TCT for an untreated sodium bromide-based brine at a density greater than 1.557 kg / 1. At densities greater than 1.557 kg / 1, sodium bromide in an untreated sodium bromide-based brine is not at rest in solution at temperatures below 21.1°C. The addition of sorbitol, as shown in Table 3, can result in a significant drop in TCT (see Sample 2). At 1,488 kg / L of Nabr, there is hardly any loss in density from the initial density of 1,497 kg / L. The data also show that it is possible to achieve densities greater than 1,557 kg / L with a TCT below -6.7°C (see Samples 3 and 4). Even higher densities of up to 1,665 kg / L can be achieved with a TCT below 15.6°C (Samples 5 and 6). Glycerol increased the TCT of the sodium-based brine, as shown in Table 7. A suppression factor fluid can be created taking into account the required operating density and the wellbore temperature, for example, the mud line temperature. Example 3. Example 3 was a comparison of the suppression factor of sorbitol and xylitol at various loadings in a Nabr-based brine. The results show that sorbitol is slightly better than xylitol at suppressing the TCT of sodium bromide-based brines. Table 4. Effect of sorbitol and xylitol on the TCT of a sodium bromide-based brine Density (kg / 1) Suppression sugar alcohol TCT (°C) Suppression factor Sample 1 1,560 None 26.7 0 Sample 2 1.556 15% by weight of sorbitol 10.6 2.1 Sample 3 1.561 20% by weight of sorbitol 10.0 1.5 Sample 4 1.557 255 by weight of sorbitol 2.2 1.8 Sample 5 1.557 30% by weight of sorbitol -6.1 2.0 Sample 6 1.555 155 by weight of xylitol 13.9 1.5 Sample 7 1.557 20% by weight of xylitol 11.7 1.4 Sample 8 1.558 25% by weight of xylitol 5.0 1.6 Sample 9 1.557 30% by weight of xylitol -0.6 1.63 Example 4. Example 4 shows the effect of various sorbitol loadings on potassium formate-based brines. The compositions are in Table 5. Table 5. Effect of sorbitol on the TCT of potassium formate-based brines Density (kg / L) Sorbitol (% by weight) TCT (°C) Suppression Factor Sample 1 1.581 None -3.3 0 Sample 2 1.461 5 -7.2 1.4 Sample 3 1.581 10 -10.0 1.2 Sample 4 1.617 0 28.9 0 Sample 5 1.617 5 25.6 1.2 Sample 6 1.617 -12.2 0.4 Although the embodiments have been described in detail, it should be understood that various changes, substitutions, and alterations may be made herein without departing from the principle and scope. Accordingly, the scope shall be determined by the claims and their appropriate legal equivalents. The singular forms un, una and el or la include plural references, unless the context clearly indicates otherwise. Optionally means that the event or circumstances described below may or may not occur. The description includes cases in which the event or circumstance occurs and cases in which it does not. Ranges can be expressed herein as from one particular value to another particular value. When such a range is expressed, it should be understood that another realization is from that particular value to that other particular value, along with all combinations within that range. As used herein and in the claims appended hereto, each of the terms comprise, have and include and all grammatical variants thereof is intended to have an open, non-exhaustive definition that does not exclude additional elements or steps. As used herein, terms such as first and second are assigned arbitrarily and are intended simply to differentiate between two or more components of an apparatus. It should be understood that the words first and second serve no other purpose and do not form part of the component's name or description, nor do they necessarily define a location or relative position of the component. Furthermore, it should be understood that the mere use of the terms first and second does not require the existence of a third component, although that possibility is contemplated within the scope.

Claims

1. A method for using a suppression factor fluid during a well activity, the method being characterized in that it comprises the steps of: introducing a suppression factor fluid into a well, wherein the suppression factor fluid comprises: 50 wt% to 95 wt% of an untreated monovalent brine; a suppression sugar alcohol, wherein the suppression sugar alcohol is present in an operative amount to achieve a suppression factor of at least 1, wherein the suppression sugar alcohol is selected from the group consisting of sorbitol, xylitol, and combinations thereof; wherein the upper density limit of the suppression factor fluid is greater than the upper density limit of the untreated monovalent brine; and a stabilizing compound, wherein the stabilizing compound operates to inhibit the degradation of the suppression sugar alcohol, wherein the stabilizing compound comprises an amine base;and terminate well activity in the well, in such a way that the suppressing sugar alcohol inhibits crystallization during well activity.

2. The method of claim 1, characterized in that the well activity is selected from the group consisting of drilling activities, production activities, and completion activities.

3. The method of claim 1, characterized in that the untreated monovalent brine is selected from the group consisting of a sodium bromide-based brine, a sodium chloride-based brine, a sodium formate-based brine, a potassium bromide-based brine, a potassium chloride-based brine, a potassium formate-based brine, a lithium bromide-based brine, a lithium chloride-based brine, a cesium formate-based brine, and combinations thereof.

4. The method of claim 1, characterized in that the suppression factor is in the range between 1 and 10.

5. The method of claim 1, characterized in that the true crystallization temperature of the suppression factor fluid is in the range between -40 °C and 21.1 °C.

6. The method of claim 1, characterized in that the amine base is selected from the group consisting of monoetanolamina (MEA), dietanolamina (DEA), trietanolamina (TEA), ethylenediamine (EDA), diethylenetriamina (DETA), triethylenetramina (TETA), tetraethylenepentamina (ΠΕΡΑ), pentaethylenetramina (PETA), pentaethylenehexamina (PEHA), aminoetilpiperazine (AEP), etilenamina E-100 (available from Huntsman Corporation), piperazina, diethylhydroxylamina (DEHA), diethylaminoetanol (DEAE), dimethyletanolamina (DMEA), metoxipropylamina (ΜΟΡΑ), morpholina, n-aminopropylmorpholina (APM), 4-[2-hidroxyetil]morpholina, diglicolamine, N-[3-aminopropyl]dianolamine, aminoethyletanolamine (AEEA) and combinations of them.

7. A method for using a suppression factor fluid during well activity, the method being characterized in that it comprises the steps of: introducing a suppression factor fluid into a well, wherein the suppression factor fluid comprises: 50 wt% to 94 wt% of a monovalent brine; 6 wt% on a dry basis to 50 wt% on a dry basis of a suppression sugar alcohol, wherein the suppression sugar alcohol is selected from the group consisting of sorbitol, xylitol, and combinations thereof; and a stabilizing compound, wherein the stabilizing compound operates to inhibit the degradation of the suppression sugar alcohol, wherein the stabilizing compound comprises an amine base; and terminating well activity in the well such that the suppression sugar alcohol inhibits crystallization during well activity.

8. The method of claim 7, characterized in that the well activity is selected from the group consisting of drilling activities, production activities, and completion activities.

9. The method of claim 7, characterized in that the untreated monovalent brine is selected from the group consisting of a sodium bromide-based brine, a sodium chloride-based brine, a sodium formate-based brine, a potassium bromide-based brine, a potassium chloride-based brine, a potassium formate-based brine, a lithium bromide-based brine, a lithium chloride-based brine, a cesium formate-based brine, and combinations thereof.

10. The method of claim 7, characterized in that the suppression factor is in the range between 0.5 and 10.

11. The method of claim 7, characterized in that the amine base is selected from the group consisting of monoethanolamine (MEA), diethanolamine (DEA), triethanolamine (TEA), ethylenediamine (EDA), diethylenetriamine (DETA), triethylenetetramine (TETA), tetraethylenepentamine (ΤΕΡΑ), pentaethylenetetramine (PETA), pentaethylenehexamine (PEHA), aminoethylpiperazine (AEP), ethyleneamine E-100 (available from Huntsman Corporation), piperazine, diethylhydroxylamine (DEHA), diethylaminoethanol (DEAE), dimethylethanolamine (DMEA), methoxypropylamine (ΜΟΡΑ), morpholine, n-aminopropylmorpholine (APM), 4-[2-hydroxyethyl]morpholine, diglycolamine, N-[3-aminopropyl]diethanolamine, aminoethylethanolamine (EEA) and combinations thereof.

12. The method of claim 1, characterized in that the true crystallization temperature of the suppression factor fluid is in the range between -40 °C and 21.1 °C.