MXPA97005491A - Chemical compounds for petroleum and oil plant - Google Patents

Abstract

The present invention relates to an invention related to a process for increasing the effectiveness of chemical compounds for production, reducing the number of compression and closing operations necessary to increase the production rate of an oil well. The process comprises injecting into a rocky oil formation a water-miscible formulation comprising as components: (a) a water-miscible surfactant that is alkyltriglycol ether and (b) at least one chemical compound miscible with water for the production of the deposit Oil or gas field, comprising an inhibitor of scale, the components of the formulation are introduced either as a single composition preformed or simultaneously in parallel or sequentially in any order towards the rock formation, through the production well

Description

CHEMICAL COMPOUNDS FOR PETROLEUM AND GAS OIL FIELD DB THE INVENTION This invention relates to chemical compounds for oilfields, in particular, with chemical compounds for oilfield and with its use.

BACKGROUND OF THE INVENTION It is well known to use various types of chemical compounds in the production of petroleum from oil wells and to increase the production of oil from these wells. One of these methods is described in US-A-3481870 which discloses methods and compositions for removing organic deposits, such as paraffin, waxes and asphalt and bituminous substances from the front or face of the production formation, in the sieve or in the lining or in the pump, tubing or well pipe. The compositions used include glycol ethers, such as for example iso-butyl triglycol ether, an oxyethylated butylphenol, isopropanol and water. However, it is not revealed that the production wells experience problems with inorganic deposits, such as inlays, or that the described process can inhibit the formation of Pl Í24-97MX incrustations. Among the chemical compounds for oilfield known are the inhibitors of scale, which are used in production wells to stop the formation of scale in the rock formation and / or in the production lines of the bottom of the well and on the surface . The formation of scale not only causes restrictions in the pore size of the rock formation (also known as "formation damage") and, consequently, the reduction in the oil and / or gas production regime, but also the blockage or obstruction of the tubular equipment and of pipe during the processing of the surface. To overcome this, the production well is subjected to what is called "closure" treatment, whereby an aqueous composition comprising an scale inhibitor is injected into the production well, usually under pressure and pushed into the formation and held there. The injected compositions are adsorbed on the surface of the rock and, in this way, inhibit the formation of scale leaching into the produced water, thus maintaining access to oil in the rock formation; This "closure" treatment needs to be done regularly, for example, at least one or more times a year if you want to maintain high levels of P1J24-97MX production and constitutes the "idle or idle time" when production does not take place. Over the course of the year, there is a reduction in total production corresponding to the number of times that time was had during the compression / closure operation, as well as a reduction in production as the fouling problem increases or accumulates. We have discovered a means and method for increasing the effectiveness of chemical compounds for production, in particular, scale inhibitors, so that the number of times compression / closure is necessary and the production rate is increased. In addition, we have discovered a formulation for this purpose, which is stable to storage and transport.

SUMMARY OF THE INVENTION In accordance with the foregoing, the present invention is a process to increase the effectiveness of chemical compounds for production, reducing the number of compression and closing operations necessary to increase the production rate of an oil well, inhibiting the formation of scale in said well, the process involves the injection into the oil rock formation of a miscible formulation in Pl 324 -97MX water comprising: (a) a water-miscible surfactant that is an alkyltriglycol ether and (b) at least one chemical compound, miscible with water, for the production of the oilfield or the gas field, which comprises an inhibitor of incrustation, under pressure and keeping the formulation in formation for a period of time to achieve closure, thus allowing the components of the formulation to be adsorbed by the oil formation and act as an inhibitor of Inlaying, the components of the formulation are introduced either as a single homogeneous and preformed composition, or simultaneously in parallel or sequentially in any order towards the rock formation. The alkyl group in the alkyltriglycol ether may be straight or branched chain and suitably has 3-6 carbon atoms, preferably 3-5 carbon atoms. The alkyl group in the alkyl triglycol ether, more preferably, has 4 carbon atoms and especially is n-butyltriglycol ether (also known as triethylene glycol mono-n-butyl ether). Where the formulation is injected into the rock formation as a single preformed composition, the Pl H24-97MX formulation in a suitable form is a homogeneous aqueous solution containing the two components in specific proportions to maintain the homogeneity of the formulation. Thus and in accordance with a specific embodiment, the present invention is a homogeneous formulation comprising, in an aqueous medium, (a) at least one surfactant comprising n-butyltriglycol ether in an amount of 1-20% in weight and (b) at least one chemical compound for the production of oilfield or gas field in an amount of 1-25% by weight. In another aspect, the present invention is a method for introducing the homogeneous formulation comprising a chemical compound for the production of the oil field or the gas field, comprising an scale inhibitor and a surfactant in a rock formation comprising petroleum. and / or gas, this process involves moving the homogeneous formulation down a production well and, thus, into the rock formation. The invention also stipulates the use of the homogeneous formulation of the invention in order to increase the effectiveness of the chemical compound for the production of the oil field or the gas field, which Pl 124-97MX comprises an inhibitor of scale in a rock formation, in particular, increasing the duration of retention of the chemical compound by the rock. By the term "homogeneous formulation" as used herein and throughout the specification, it is meant that the formulation is a single-phase system. That is to say, each component is in itself homogeneous and is miscible in water when it is introduced sequentially or simultaneously into the rock formation, and is also homogeneous if it is introduced into the rock formation as a single preformed composition. It will be evident that when the components of the formulation are introduced simultaneously but separately or, sequentially, they are not introduced as a single preformed composition and hence the concept that the formulation is homogeneous does not apply. However, in this case, it is preferable that each of the components used is itself homogeneous and also that it is miscible in water. The pH of the formulation in a suitable form goes from 0.1-6.0 and as a whole it is of importance or significance only when a preformed composition is used. The pH of component (b) is preferably controlled as specified. In this way, the surfactant used suitably comprises at least one alkyl triglycol ether and The I24-97MX at least one chemical compound for production and remains clear and stable in a range or temperature range from the environment to at least about 45 ° C. The surfactant in suitable form is present in the formulation in an amount ranging from 1-20% by weight, preferably from 5 to 15% by weight, more preferably from 5 to 12% by weight. In the present invention, it is possible to use by-product streams from the manufacturing processes of the glycol ether containing a high proportion of alkyltriglycol ethers, such as, for example, n-butyltriglycol ether. One of these by-product streams comprises about 75% n-butyltriglycol ether, about 2.5% by weight butyl diglycol ether, about 19% butyl tetraglycol ether and about 2% butyl pentaglycol ether. The relative proportions of the components (a) and (b) of the formulation can vary within wide ranges depending on whether the components are introduced into the rock formation simultaneously, sequentially or as a single preformed composition consistent with the need to maintain the homogeneity at the operating temperatures and the salinity of the formulation. For example, at relatively higher concentrations of the surfactant or at relatively higher temperatures or at In the case of extremely low temperatures, it is possible for a preformed formulation to lose its homogeneity due to the reduced solubility of one or more of the components of the formulation under such conditions. In these cases, small quantities of a solubilizing agent, such as for example a lower aliphatic alcohol, especially methanol or ethanol or, used to partially replace the surfactant in the formulation to restore the homogeneity of the formulation can be added to the preformed non-homogeneous formulation. Thus, the preformed homogeneous formulations of the present invention may contain, in addition to the alkyltriglycol ether, a cosolvent such as, for example, a lower aliphatic alcohol, especially methanol or ethanol. The aqueous medium of the formulation can be fresh, tap, river, sea, produced or forming water, with a total salinity of for example, 0-250 g / 1, such as for example 5-50 g / 1 and can have a pH of 0.5-9. When seawater is used, the formulation normally has a very acidic pH in the region of 0.1 to 1.5, due to the presence of a highly active chemical compound, which is used in production, which comprises an inhibitor of scale. In these cases, it may be necessary to neutralize the acidity of the formulation P1324-97MX using an alkali metal hydroxide, especially sodium hydroxide, potassium hydroxide or lithium hydroxide in order to bring the pH of the formulation within the preferred range of 0.1-6.0. It has been found, for example, that the use of lithium hydroxide as a neutralizing agent instead of the other alkali metal hydroxides allows the tolerance of relatively higher levels of the surfactant in the formulation, when required to maintain the homogeneity of the formulation. The chemical compound for the production of the oil field or the gas field comprises an inhibitor of scale. The scale inhibitor is effective in stopping calcium and / or barium scale with threshold amounts rather than stoichiometric amounts. It can be a water-soluble organic molecule with at least 2 carboxylic acid and / or phosphonic acid groups and / or sulfonic acid groups, for example 2-30 of these groups. Preferably, the scale inhibitor is an oligomer or a polymer or it can be a monomer with at least one hydroxyl group and / or an amino nitrogen atom, especially in a hydroxycarboxylic acid or hydroxy or aminophosphonic acid or sulphonic acid. The inhibitor is mainly used to inhibit the calcium and / or barium scale. Examples of these compounds used as inhibitors are the P1324-97MX aliphatic phosphonic acids with 2-50 carbons, such as for example hydroxyethyl diphosphonic acid and aminoalkyl phosphonic acids, for example, polyamomethylene phosphonates with 2-10 N atoms, for example each carrying at least one acid group methylene phosphonic; examples of the latter are ethylene diamine tetra (methylene phosphonate), diethylenetriamine penta (methylene phosphonate) and triamine- and tetramine-polymethylene phosphonates with 2-4 methylene groups between each atom of N, at least 2 of the numbers of the methylene groups in each phosphonate they are different (for example, as described further in published EP-A-479462, the disclosure of which is incorporated herein by reference). Other scale inhibitors are polycarboxylic acids, such as for example lactic or tartaric acids and polymeric anionic compounds such as for example polyvinyl sulfonic acid and poly (meth) acrylic acids, optionally with at least some phosphonyl or phosphinyl groups such as in phosphinyl polyacrylates. Suitable scale inhibitors are at least partially in the form of their alkali metal salts, for example, sodium salts. The amount of the chemical compound for production, which comprises an inhibitor of scale, used is in the range from 1-25% by weight P1324-97MX of the total formulation, suitably from 5-15% by weight, preferably from 6-10% by weight. Within these ranges, the amount used would depend on the nature of the chemical compound used and its intended purpose consistent with the formulation is homogeneous. It is important with the formulations of the present invention, especially those which comprise a preformed homogeneous composition, to remain clear and stable at a temperature range from ambient to at least about 45 ° C. However, within the concentration ranges of the components specified above, it is possible to devise formulations that remain stable over a much wider temperature range, for example, from ambient temperature to the temperature of the production well (e.g. 90 to about 150 ° C, especially around 110 ° C) into which the formulation will be introduced. In the present invention, when the components of the formulation are injected under pressure into the production well, either as a preformed formulation, simultaneously or sequentially, the chemical compounds for production of the formulation are adsorbed by the rocks and are retained for periods of time. relatively long Using a molecule P1324-97MX relatively small, such as for example a C3-C6 (alkyl) triglycol ether as the surfactant, avoids the use of large molecules of surfactants (having alkyl groups> Cg) thus minimizing any risk that surfactant aggregates are formed, which in turn can result in high viscosity emulsions that cause blockage or blockage of the wells. Thus, said formulation may contain, in addition, other components such as for example (i) other chemical compounds for production or (ii) cosolvents which, when necessary, enable the formulation to remain stable at relatively high temperatures or when the surfactant is used in concentrations in the upper quartile of the specified range or range. However, these formulations must be substantially free of water immiscible components. Examples of other chemical compounds for production include compounds that can be inhibitors of (i) corrosion, (ii) formation of the gas hydrate, (iii) wax or (iv) deposits of asphaltene or can be hydrogen sulfide scavengers or a wax dispersant. In this way: (i) corrosion inhibitors are compounds to inhibit corrosion in steel, especially low P1324-97MX anaerobic conditions and can especially be film formers, capable of being deposited as a film on a metal surface, for example, a steel surface such as the wall of a pipe. These compounds may be N-hetrocyclic hydrocarbyl compounds of long non-quaternized aliphatic chain, wherein the aliphatic hydrocarbyl group can be defined according to the above hydrophobic group; mono- or di-ethylenically unsaturated aliphatic groups, for example 8-24 carbons such as oleyl, are preferred. The N-heterocyclic group can have 1-3 nitrogen atoms in the ring with 5-7 atoms in each ring; imidazole and imidazoline rings are preferred. The ring may also have an aminoalkyl, for example, 2-aminoethyl or hydroxyalkyl, for example, a 2-hydroxyethyl substituent. Oleyl imidazoline can be used. (ii) a gas hydrate inhibitor can be a solid polar compound, which can be a polyoxyalkylene or alkanolamine or tyrosine or phenylalanine compound. (iii) an asphaltene inhibitor can be an amphoteric fatty acid or a salt of an alkyl succinate, while the wax inhibitor can be a polymer such as an olefin polymer, for example, polyethylene or a copolymer ester, for example , a Pl 324-97MX ethylene-vinyl acetate copolymer and the wax dispersant can be a polyamide. The hydrogen sulphide scrubber can be an oxidant, such as for example an inorganic peroxide, for example, sodium peroxide or chlorine dioxide or an aldehyde, for example 1-10 carbons such as for example formaldehyde or glutaraldehyde or (meth) acrolein. The preformed homogeneous formulations of the present invention, when used, can be prepared in a suitable manner by adding the surfactant (a) to an aqueous solution of the chemical compound for the production of the oilfield or the gas field (b) comprising an inhibitor. of incrustation, followed by gentle mixing. If the material initially prepared is cloudy or cloudy, then minor adjustments to the relative proportions of the ingredients or a change in the nature or amount of the cosolvent used or in the temperature will be necessary. Its viscosity in a suitable form is such that at the temperature of the vessel, for example at 100 ° C, they are easy to pump to the bottom of the well. The preformed formulations of the present invention can be prepared by a concentrate of ingredients (a) and (b), which can be transported as such to the site of use. Where they will be mixed with the aqueous medium in the appropriate proportions to obtain P1J24-97MX the desired homogeneity and in which the chemical compound has dissolved. The preformed formulation can be injected, suitably under pressure, into a petroleum producing zone, eg, a rock formation, through a production well, for example, up to the core, followed by a separate liquid to force the preformed formulation towards the oil producing area; The liquid can be used as a drag stream and can be seawater or diesel oil. The formulation is then left ("closed") in the oil zone, while oil production is temporarily stopped. During this process, the injected formulation percolates through the oil zone under the injection pressure. In the closing period, the injected formulation comes in contact with the reservoir fluids and forms a two-phase or three-phase in-situ system, which can be in the form of an emulsion and which exhibits the surface behavior and desired phase. This is the so-called "compression" effect that allows the maintenance of oil recovery from these zones. A desirable contact time of 5-50 hrs. , for example, 20-30 hrs. it is often obtainable with the formulations of the present invention. After this period, oil production can be restarted. In the case where P1324-97MX The chemical compound for production is an inhibitor of scale, the oil production regime will initially be high, as will the soluble calcium content of the water produced. Over time, for example, 2-4 months, the production rate will decrease and the soluble salt content will also decrease meaning possible problems of scaling in the rock formation, so that production can be stopped and a new aliquot of the formulation injected In the well. Similar methods can be used to obtain asphaltene inhibition, wax inhibition or dispersion and hydrogen sulfide depletion, while corrosion and gas hydrate inhibition, the formulation is usually injected to the bottom of the well in Continuous form. A further particularity of the formulations of the present invention is that when a multi-phase composition comprises, for example, an scale inhibitor, the oil and the alkyltriglycol ether are recovered on the surface, after the above compression procedure and with the Subsequent cooling thereof, most of the glycol ether enters the aqueous phase instead of the oil phase of this composition. In this way, the glycol ether does not cause any problem either in the subsequent operations of Pl 24-97MX production or refining, such as for example, contribute to any nebulous formation in fuels due to the presence of water solubilized in the glycol ether. In addition, if the separated aqueous phase is discharged into the sea, then the biodegradation of the dissolved glycol ether can be relatively rapid in the thermal sea layer, thereby minimizing contamination. In addition, the formulations of the present invention can increase the effectiveness of the chemical compound for oilfield or gas field, for example, in two for the case of scale inhibitors, so that less chemical compound would normally be needed per year and would also be required. they would reduce the dead time due to the application of the chemical compound and the closure, correspondingly increasing the production rate. The process can be operated in an equally efficient manner by injecting the components of the formulation sequentially into the production well. The present invention is illustrated in the following examples.

Example 1: 1.1 A general formulation capable of remaining with a clear and bright appearance between room temperature and 95 ° C and used for the following experiments had the P1324-97MX following composition: Dequest 2060S (inhibitor of 10 parts by weight inlay, ex Monsanto) Seawater 75 parts by weight Surfactant 15 parts by weight The pH of this formulation was not monitored. 1. 2 A stability test was carried out using 15 parts of a commercially mixed glycol ether surfactant (according to the invention) having the following approximate composition in the general formulation (1.1) above: n-butyltriglycol ether 75% by weight n-butyl diglycol ether 2.5% by weight n-butyltetraglycol ether 10.0% by weight n-butylpentaglycol ether 2.0% This formulation resulted in a homogeneous yellow solution. With the heating of a sample of this homogeneous formulation from room temperature (when stable in a single part) with agitation, up to 95.5 ° C, a phase transition was observed and a nebulosity began to appear in the formulation. Above this temperature and remaining without agitation, a P1J24-97MX separate colorless phase above a larger lower yellow phase (presumably, the upper part was mainly n-butyltriglycol ether).

Example 2; The objective of this example was to determine if each of the above formulations when mixed with crude oil Forties Main-Oil Line Fluids (FMOLF) generates an intermediate phase in a mixture of three phases (according to Nelson, RC and Pope, GA in an authentic publication entitled "Phase Relationships in Chemical Flooding" publication No. SPE 6773 of the Society of Petroleum Engineers of USA, published by the American Institute of Mining, Metallurgical and Petroleum Engineers, Inc. (1977)) at 95 ° C, meaning in this way the ability of formulations to drag oil (which can otherwise be trapped in rock formations) by the formulations tested. With the heating of a homogeneous yellow solution of the formulation described in (1.2) above (lOg, containing l.5g of the commercial surfactant mixture) with stirring in the presence of FMOLF (2g), a three-phase system was observed. 95 ° C. These three phases were a superior black liquid (presumably primarily crude oil), an orange-red phase P1324-97MX average (presumably mainly the commercial surfactant mixture) and a yellow lower phase (presumably mainly Dequest aqueous solution). It was observed that this three-phase system persisted for seven days and, presumably, would have persisted indefinitely. Furthermore, with the agitation, it was observed that the middle or intermediate phase broke easily forming droplets or filaments, which were attracted downwards towards the lower phase. Upon leaving them at rest, the intermediate phase and the lower phase wet the glass wall of the test container to a similar degree. These observations were consistent with the low interfacial tension between the aqueous and oily phases, as described in Nelson and Pope in the publication referred to above.

Example 3; As a general procedure, a homogeneous formulation having the same general composition of Example 1 above was used for the following experiments. However, in this case, first 10 parts of Dequest 2060S were mixed with 75 parts of sea water and then the pH was adjusted using either solid sodium hydroxide (Examples 3.1-3.3) or solid lithium hydroxide monohydrate ( Examples 4.1-4.3) for P1J24-97MX bring it to a value of 2. As in Example 1 above, the amount of surfactant used in each case was 15 parts by weight. As a result of controlling the pH, this formulation remained homogeneous (ie, clear and bright in appearance) between room temperature and 110 ° C. The objective of these Examples was to determine if a ternary mixture formed by the above formulation, when mixed with North Alwyn crude oil from the North Sea of the United Teyno (Density No. API from 37.2 to 42.1) as published in The Geological Society, in "United Kindom Oil and Gas Fields 25 Years Commemorative Volume", Memory No. 14, Edited by IL Abbotts (1991), generated an intermediate phase at 110 ° C as described in Example 2 above. 3. 1 An experiment was carried out with a homogeneous formulation containing 15 parts by weight of the commercial surfactant mixture, used in Example 1.2 above. Upon heating a sample of this formulation from room temperature (when it was in a single phase) with stirring, a phase transition between 48 and 49 ° C was observed when the formulation appeared nebulosity.

P1324 - 97MX 3.2 An additional experiment was carried out using the same formulation of Example 3.1, except that 7 parts by weight of the commercial surfactant mixture used in the formulation of this example were replaced with 7 parts by weight of methanol. By heating a sample of this formulation containing methanol in a pressure tube Buchi glass, from room temperature (when it was in a single phase) to 90 ° C, and no phase transition was observed. This experiment shows that when formulations containing a relatively higher concentration of the surfactant are used, the non-homogeneity of the formulation can be rectified by replacing a part of the surfactant with methanol and in this way the homogeneity of the formulation can be restored and the stability thereof improved. in a significant way 3. 3 With heating and stirring a sample of the formulation according to Example 3.2 (25g, containing 2.0g of the commercial surfactant mixture of Example 1.2 and 1.75g of methanol) in the presence of North Alwyn crude oil (2g) ) added in a Buchi glass pressure tube, a three phase system at 110 ° C was observed. These phases and their behavior were Pl 124-97MX similar to those of the formulation of Example 2 above.

Example 4; 4.1 A formulation containing 15 parts by weight of the commercial surfactant mixture of Example 1.2 above, but otherwise having the general composition described in Example 3 above, was heated and gradually stirred in a glass Buchi pressure tube, starting at room temperature when the formulation had only one phase. A phase transition was observed between 67 and 68 ° C when nebulosity began to appear in the formulation. 4. 2 The above experiment 4.1 was repeated with the exception that 6 parts by weight of the commercial surfactant mixture of the formulation were replaced with 6 parts by weight of methanol. With gradual heating and agitation, no phase transition of this revised formulation containing methanol was observed in a Buchi glass pressure tube starting at room temperature (when the formulation exhibited only one phase) up to 109 ° C and then raising the temperature at 115 ° C after one hour. Again, this experiment shows that when formulations containing a concentration are used P1324-97MX relatively higher surfactant, the non-homogeneity of the formulation can be rectified by replacing a part of the surfactant with methanol and, in this way, the homogeneity of the formulation can be restored and the stability of the formulation improved significantly. 4. 3 Upon heating and stirring a formulation mixture according to Example 3.2 (30.0 g, containing 2.7 g of the surfactant used in Example 1.2 and 1.8 g of methanol) with added North Alwyn crude oil (4 g) in a tube of Buchi glass pressure, a three phase system at 110 ° C was observed. These phases and their behavior were similar to the results of Example 2 above.

Example 5: The inhibition effectiveness of the scale of the homogeneous formulation of Example 3.2 above was compared to a control formulation (not according to the invention) containing only Dequest 2060S (10 parts by weight) and sea water (90 parts by weight) for a simulated compression treatment process. From a sandstone core of a well in the Brent group of the North Sea, vertical cores of 15 cm long were drilled. Each core of 15 cm was eliminated The oil ia24-97MX by solvent extraction successively with toluene and then with methanol / chloroform, before being mounted in a vertical column adjusted or adapted with inlet and outlet outlets. Degassed seawater at pH 5.5 was passed through the core at room temperature until saturation. 5 pore volumes of degassed Brent crude oil (filtered to remove material greater than 10 μm) was passed to the core at 150 ml / hr until no more water was collected from the outlet. The core was then heated to 110 ° C, simulated reservoir temperature for 24 hours, before injection at 150 ml / hr degassed sea water at a pH of 5.5, until no more oil was collected. The core then had a residual oil saturation and a residual saturation of brine and, thus, the bottom of the oil rock formation was simulated. The core was cooled to 40 ° C without gas inlet and then at 30 ml / hr, 8-10 pore volumes of the inhibitor medium (as described below) were injected until saturation. After which, the intakes were closed and the core was reheated to 110 ° C and held there for 17 hours. Degassed seawater at a pH of 5.5 was then passed through the core at 30 ml / hr and samples of the effluent were collected periodically and the level of the inhibitor was analyzed until the concentration Pl-I24-97MX of the inhibitor fell below 5 ppm. The core was then cooled and cleaned by stripping with methanol before drying and examination by scanning electron microscopy to verify any effect of the treatment on the clay or the morphology of the pore; none were observed. Two sets of experiments were developed using the above procedure: one with the formulation described in Example 3.2 above and the other with a control containing the relevant inhibitor at the same wt% and pH = 2 and only seawater. The ratio of the level of the effluent inhibitor to the volume of seawater passing through the core (expressed as the number of pore volumes of the solution) is a measure of the amount of inhibitor taken or captured initially by the rock formation and of its rate of release, that is, a measure of the rate or rate of elimination of the inhibitor of rock formation during production (ie, its resistance to leaching) and hence, which is a measure of its effectiveness in inhibiting the formation of incrustation with time. The results appear below in Table 1.

P1 24-97MX TABLE 1 Example 6: This example was carried out using compacted "instead of the core used in Example 5. Two sets of tests were carried out: (i) a repetition Pl 24-97MX direct from Example 5 using a homogeneous solution and (ii) repeating Example 5 but now using a sequential addition in which the surfactant was initially introduced into the compacted sand, followed by a broadening of the scale inhibitor. The formulation for part (i) above was prepared from the following components: inhibitor used - Dequest 2060S - 10 parts by weight amount of seawater used - 75 parts by weight Commercial surfactant used a mixture of 8 parts by weight of the one used in example 5 and 7 parts by weight of residual oil of methanol residual oil - a crude oil of the Forties deposit (dry and without additive) pH - 2.0 temperature - 110 ° C After this the process was repeated for the control purpose (baseline) of the experiment in which the homogeneous formulation containing 90 parts by weight of seawater and 10 parts by weight of Dequest 2060S was used in the absence of surfactants. Test (ii) was carried out using compacted sand in a 1,524 meter (5 feet) metal tube packed with Clashach sand. The package was washed by dragging with residual oil (using fluid from the P1324-97MX Forties Field main line) and in the same way washed by flooding or dragging with seawater using the same temperatures (110 ° C) and the same flow rates as in Example 5 above. In these experiments, the pre-drag data were obtained by sequential additions, first of an 8% by weight solution of the commercial surfactant described above, dissolved in seawater (the pH was adjusted as required), a closure at 110 ° C for 12 hours, followed by the addition of a broadening inhibitor similar to that used for the baseline data without surfactant. The baseline data were repeated using the compacted sand but using a 10% by weight solution of Dequest 2060S in seawater adjusted to a pH of 2.0, but without the surfactant in order to make more accurate comparisons with the compacted sand The results are shown in Table 2 below.

P1 24-97MX TABLE 2 Example 7 This Example was carried out with a Tarbert core material using the procedure described in Example 5 above and with a homogeneous mixture of the surfactant and Dequest scale inhibitor 2086 shown in the formulation below: Pl S24-97MX The inhibitor was used in a concentration of 4% by weight and the mixture was prepared in distilled water. In this way, the complete formulation used was: -7% by weight of Dequest 2086 in water - 85 parts distilled with a pH adjusted to 2.0 Distilled water - 7 parts Formulation of the commercial surfactant of the - 8 parts Examples 1.2 above The baseline data were obtained using Dequest 2086 in seawater (at 15.7% by weight as supplied, corresponding to 5% by weight of active material) adjusted to a pH of 5.45. The data shown in Table 3 are for a homogeneous formulation as when used as described in Example 5 above. The results are shown in Table 3 below: P1324-97MX TABLE 3 Pl S24-97MX

Claims (9)

NOVELTY OF THE INVENTION Having described the present invention, it is considered as a novelty and, therefore, the content of the following CLAIMS is claimed as property;
1. l. A process to increase the effectiveness of chemical compounds for production, by reducing the number of compression and closure operations necessary to increase the production rate of an oil well, inhibiting the formation of scale in the well, the process comprises the injection into the oil rock formation of a water-miscible formulation comprising: (a) a water-miscible surfactant which is an alkyltriglycol ether and (b) at least one chemical compound miscible with water for the production of the oilfield or the gas field, which comprises an inhibitor of scale, under pressure and keeping the formulation in formation for a period to reach the closure, thus allowing the components of the formulation to be absorbed by the oil formation and act as an inhibitor of scale, the components of the formulation are introduced either as a single P1324-97MX homogeneous composition preformed or simultaneously in parallel or sequentially in any order towards the rock formation. 2. A process according to claim 1, wherein the surfactant comprises at least one alkyltriglycol ether which is present in the formulation in an amount ranging from 1-20% by weight. 3. A process according to claim 1 or 2, wherein the alkyl group of the alkyltriglycol ether is straight or branched chain and has 3-6 carbon atoms. 4. A process according to any of the preceding claims, wherein the alkyl group of the alkyl triglycol ether has 3-5 carbon atoms. 5. A process according to any of the preceding claims, wherein the alkyltriglycol ether group is n-butyltriglycol ether (also known as triethylene glycol mono-n-butyl ether). 6. A process according to any one of the preceding claims, wherein the surfactant is a by-product stream from the manufacturing processes of glycol ester containing a high proportion of the n-butyltriglycol ether. 7. A process according to claim 6, wherein the by-product stream comprises about 75% by weight of the n-butyltriglycol ether, approximately P1324-97MX
2. 2. 5% by weight of butyl diglycol ether, about 19% butyltetraglycol ether and about 2% butylpentaglycol ether. A process according to any one of the preceding claims, wherein the amount of the chemical compound for the production used is in the range of 1-25% by weight of the total formulation. 9. A process according to any of the preceding claims, wherein the formulation is injected into the rock formation as a single preformed homogeneous composition, the formulation is an aqueous solution containing the two components in specific proportions to maintain the homogeneity of the formulation . A process according to any one of the preceding claims, wherein the formulation is a homogeneous formulation comprising in an aqueous medium, (a) at least one surfactant comprising n-butyltriglycol ether in an amount of 1-20% in weight and (b) at least one chemical compound for the production of the oilfield or gas field, comprising an scale inhibitor in an amount of 1-25% by weight. 11. A process according to claim 5, wherein the method of introducing a chemical compound, for the Pl 324-97MX production of the oilfield or gas field, comprising an scale inhibitor and the surfactant, in a rock formation comprising oil and / or gas, wherein the process comprises passing a preformed homogeneous formulation of the compound chemical for the production and of the surfactant to a production well and then to the rock formation. 12. A process according to any of the preceding claims, wherein the formulation is a single prechromed composition comprising alkyltriglycol ether and at least one chemical compound for production comprising an scale inhibitor, the composition remains clear and stable at a temperature range from ambient to minus approximately 45 ° C. A process according to any of the preceding claims, wherein the formulation further contains other components that include (i) other chemical compounds for production or (ii) cosolvents that allow the formulation to remain stable at relatively higher temperatures or when the surfactant is used in concentrations in the upper quartile of the specified range and, it is substantially free of water immiscible components. 14. A process according to claim 12, in P1.324-97MX where the cosolvent is a lower aliphatic alcohol selected from methanol and ethanol. 15. A process according to any of the preceding claims 1-8, wherein each of the formulation components when sequentially injected into the rock formation is in a homogeneous state regardless of whether it is used pure or as an aqueous solution of the same. 16. A process according to any of the preceding claims, wherein the aqueous medium of the formulation is obtained from fresh water, tap water, river water, seawater, produced or forming water, with a total salinity of, for example, 0-250 g / 1 and has a pH of 0.5-9. 17. A process according to any of the preceding claims, wherein the seawater is used as the aqueous medium and the formulation has an acidic pH in the region of 0.1 to 6.0. 18. A process according to any of the preceding claims, wherein the chemical compound for the production of the oil field or the gas field is an inhibitor of scale which is effective to stop the formation of calcium and / or barium scale. 19. A process according to claims 17 or 18, wherein the scale inhibitor is a molecule P1324-97MX organic soluble in water with at least two carboxylic acid and / or phosphonic acid and / or sulfonic acid groups. 20. A process according to claim 17 or 18, wherein the scale inhibitor is a monomer, oligomer or a polymer having at least one hydroxyl group and / or an amino nitrogen atom. 21. A process according to claim 19, wherein the scale inhibitor is an aliphatic phosphonic acid with 2-50 carbons or an aminoalkyl phosphonic acid, each carrying at least one methylene phosphonic acid group. 22. A process according to claim 21, wherein the scale inhibitor is selected from the group consisting of ethylenediamine tetra (methylene phosphonate), diethylenetriamine penta (methylene phosphonate) and the triamine- and tetramino- polymethyl-: phosphates with no 2- 4 methylene groups between each N atom. A process according to claim 19, wherein the scale inhibitor is a polycarboxylic acid selected from lactic acid, tartaric acid and poly (meth) acrylic acid. 24. A process according to any of the preceding claims, wherein the other chemical compound for the production of the formulation is a P1324-97MX inhibitor of: (i) corrosion, (ii) formation of gas hydrate, (iii) wax, or (iv) deposit of asphaltene, -o is a hydrogen sulphide scrubber or a wax dispersant. Pl 324-97MX