• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
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    • 专利摘要:
    The present invention relates to a method for adjusting to a predetermined value the rate of an inhibitor of mineral deposits or corrosion injected into a gas or oil well. It also relates to the use of the time resolved fluorescence method for detecting and quantifying an inhibitor of mineral deposits or corrosion in a fluid from a production well of oil or gas.
    公开号:FR3015547A1
    申请号:FR1363287
    申请日:2013-12-20
    公开日:2015-06-26
    发明作者:Christian Hurtevent；Salima Baraka-Lokmane；John-Richard Ordonez-Varela；Olivier Tillement；Thomas Brichart；Matteo Martini
    申请人:Centre National de la Recherche Scientifique CNRS；Universite Claude Bernard Lyon 1 UCBL；Total SE；
    IPC主号:
    专利说明:

    [0001] The present invention relates to a method for adjusting to a predetermined value the rate of an inhibitor of mineral deposits or corrosion injected into a gas well. or oil. It also relates to the use of the time resolved fluorescence method for detecting and quantifying an inhibitor of mineral deposits or corrosion in a fluid from a production well of oil or gas. BACKGROUND OF THE INVENTION During the exploitation of oil or gas fields, the recovery of oil can be improved by injecting water into the deposit, via an injection well, so as to push oil from the deposit out of the basement, by at least one other well called production well. The interaction of the injected water with the tank containing the gas, the oil and the groundwater can result in the formation of chemical species likely to cause malfunctions of the installations. More particularly, deposits of barium sulfate, calcium carbonate or zinc sulphides and lead, for example, are particularly likely to form under operating conditions at high pressure and high temperature or during implementation. contact with the injected brine to extract oil or gas with the hydrogen sulphide or ions contained in the reservoir. The production of reservoir or aquifer water simultaneously with oil or gas can lead to the same phenomena. These mineral deposits are likely to obstruct the flow channels in the formation, pollute pipelines and surface equipment and block pumping systems. More generally, mineral deposits or corrosion phenomena can occur under different operating conditions.
    [0002] To prevent or slow down these phenomena, additives are injected into the underground formation or into the gas or oil wells. An example of such additives is inorganic deposit inhibitors and corrosion inhibitors. The injection of a fluid containing an inhibitor capable of preventing the formation of problematic crystals, of preventing their growth or of dispersing them thus makes it possible to counter the aforementioned drawbacks and to avoid or delay dismantling of the installations with a view to their cleaning.
    [0003] The dosage of these inhibitors, however, is an essential aspect of the production of hydrocarbons, to ensure that they are present in sufficient quantity to fulfill their function and, if necessary, to inject in time an additional amount inhibitor, adjusted to take into account the economic constraints of the process and its environmental impact. The methods currently used to dose these inhibitors are often not very precise and / or long and require equipment often insufficiently adapted to the operating conditions. One of the examples of these methods is the determination of methyl orange corrosion inhibitors. Although this technique is very flexible, it is notoriously unreliable and has a very high relative uncertainty on the results.
    [0004] For the determination of molecules inhibiting mineral deposits, a precise chemical analysis is necessary on a certain number of specific elements of one of the molecules used (measurement of the level of nitrogen or of phosphorus for example, method called Hyamine for the polymers) . These measurements can be performed either by mass spectrometry and / or by separation and concentration using analytical devices such as high performance liquid chromatography (HPLC). These techniques are both complex and difficult to implement. The development of a reliable and rapid detection method is also hampered by the fact that these inhibitors are generally so effective that they are present in the injected fluid only up to a few ppm, and by the presence in the fluid consisting of operating waters of a variety of compounds such as salts and organic residues. Due to the presence of these compounds, the fluid produced produces in particular an intrinsic fluorescence that prevents the detection of inhibitors, possibly labeled with a fluorescent probe, using traditional fluorescence techniques. Finally, the production sites are generally located in remote locations, away from local analysis laboratories, which is an additional constraint.
    [0005] It would therefore be desirable to be able to dose these inhibitors directly on site, in the production water, using a simple, reliable and accurate method, usable on a variety of inhibitors of mineral deposits and corrosion and can be put implemented using compact devices to be moved easily. The inventors have demonstrated that these needs could be met by combining these inhibitors with a lanthanide ion and using the time resolved fluorescence method. This method makes it possible to overcome the natural fluorescence of operating water, which has very short emission times, and to harvest only the light emitted after a delay of a few microseconds to a millisecond, preferably 100 microseconds to one millisecond, resulting from the fluorescence of the inhibitors thus marked. The dosage of the inhibitors can then be carried out by quantizing the emitted phosphorescence signal, with an accuracy of less than 10 ppm, or even less than 1 ppm. This method also has the advantage of specifically identifying the type of inhibitor (mineral deposition or corrosion), even when it is present in a complex fluid formed by the production water in the oil medium, depending on its optical signature, simultaneously exploiting the excitation and emission spectra and the lifetimes of the transmitted signals.
    [0006] SUMMARY OF THE INVENTION The present invention relates to a method for adjusting to a predetermined value the rate of an inhibitor of mineral deposits or corrosion injected into a gas or oil well, comprising the following successive steps: of the inhibitor using a lanthanide, - the detection and quantification of the labeled inhibitor, by time resolved fluorescence, in the fluid extracted from the production well, and - if necessary, the injection into the well of an additional amount of inhibitor to reach said predetermined value. It also relates to the use of the time resolved fluorescence method for detecting and quantifying an inhibitor of mineral deposits or corrosion in a fluid from an oil or gas production well. DETAILED DESCRIPTION OF EMBODIMENTS The method according to the invention essentially comprises the detection and quantification, by time resolved fluorescence, of a lanthanide-labeled mineral deposition inhibitor or corrosion which is present in the extracted fluid. an oil or gas production well. By "mineral deposit inhibitor" is meant a compound capable of preventing or slowing down the formation (ie nucleation and / or growth) of mineral salt crystals chosen in particular from: calcium carbonate calcium sulphate, barium sulphate, strontium sulphate, sulphides of zinc, lead and iron, and mixtures thereof. The inorganic deposit inhibitors that may be used according to the invention may especially be chosen from: polyphosphates, such as sodium tripolyphosphate (STPP), sodium hexametaphosphate (SHMP), organophosphonates, such as amino-tri acid (methylene phosphonic) or AMP, 1-hydroxyethylidene-1,1-diphosphonic acid or HEDP, ethylenediamine tetra (methylene phosphonic acid) or EDTMP, hexamethylenediamine tetra (methylene phosphonic acid) or HMTMP, diethylenetriamine acid penta (methylene phosphonic acid) or DETMP, hydroxyethylamino-di (methylenephosphonic acid) (HEMPA), polycarboxylic acids such as 2-phosphonobutane 1,2,4-tricarboxylic acid or PBTC, poly (acrylic acid) or PAA, poly (methacrylic acid) or PMAA, poly (maleic acid) or PMA, - sulfonic acid-functional polymers, such as copolymers of styrene sulfonic acid and (poly) carboxylic acid, in particular copolyamines. styrene sulfonic acid and maleic acid monomers, copolymers of styrene sulfonic acid and (poly) amidoamine, homo- and copolymers of vinylsulfonate, in particular copolymers of vinylsulphonate, styrene and maleic anhydride, alkyldiphenyl ether sulfonates and copolymers of acrylamidomethylpropanesulphonic acid (AMPS), maleic acid and acrylic acid, - polyphosphinocarboxylic acid (PPCA) optionally sulfonated, - polyethyleneimine (PEI), - silicone polymers, in particular especially polydimethylsiloxanes, functionalized with amine groups, and - quaternary ammonium-based copolymers, such as copolymers of acrylamide, quaternary ammonium and optionally acrylate and copolymers of acrylamide, diallyldimethylammonium salt and optionally acrylate. By "corrosion inhibitor" is meant a compound capable of reducing the corrosion rate of a material, typically a metal or a metal alloy, due to the action on this material of an oxidant such as dioxygen or Examples of corrosion inhibitors include mono-, di- and triamines such as cyclotiexylamine, hexylamine, morpholine or octadecylamine, as well as aminoalcohols such as diethylaminoethanol, quaternary ammoniums and the like. betaine. Lanthanides used as markers according to the invention may be chosen from elements of atomic number 57 (lanthanum) to 71 (lutetium), such as Pr, Nd, Sm, Eu, Tb, Dy, Ho, Er, Tm and Yb, as well as their mixtures and / or alloys. Preferred lanthanides for use according to the invention are europium (Eu) and terbium (Tb). According to a first embodiment of the invention, more particularly adapted to polymeric type inhibitors, labeling of the inhibitor with lanthanide can be carried out in a fluid injected into the well. The optical signature of the labeled inhibitor is recorded, corresponding to its emission, excitation and lifetime characteristics, which is then compared with the data collected from the extracted fluid. It is thus possible to identify and quantify the labeled inhibitor within the fluid extracted from the production well.
    [0007] In this embodiment of the invention, the labeling of the inhibitor with lanthanide can be carried out in different ways.
    [0008] In a first variant adapted in particular to polymeric type inhibitors, a molecule complexing lanthanide may be grafted on the backbone of the inhibitor. By "complexing molecule" is meant any molecule capable of forming with the lanthanide a complex comprising at least two coordination bonds. A complexing molecule having a coordination of at least 6, for example at least 8, and a dissociation constant of the complex with the lanthanide greater than 10 and preferably greater than 15 are preferably chosen. These complexing molecules are advantageously chelating polydentate molecules chosen in particular from polyamines and polycarboxylic acids, such as diethylene triamine pentaacetic acid (DTPA), ethylene diamine tetraacetic acid (EDTA) and DOTA-GA (nitrogenous macrocycle carrying 3 carboxyl functions and an anhydride function glutaric), DOTAM (nitrogenous macrocycle carrying 4 amine functions) and the DO3AM (nitrogenous macrocycle carrying 3 amine functional groups and an aminoethylethanamide function. the number of chelating molecules per molecule of inhibitor does not disturb the operation of the latter. ariante, adapted more particularly to chelate type inhibitors having a complexing constant with lanthanide ions greater than 10, the labeling of the inhibitor can be carried out by complexing the lanthanide with the aid of the inhibitor. In this variant, the labeled inhibitor molecules can represent from 1/100 to 1/1000 of the total inhibitor molecules injected into the well.
    [0009] According to a second embodiment of the invention, the inhibitor can be labeled in the fluid extracted from the production well, after the extraction step. In this embodiment, lanthanide ions are introduced into the extracted fluid and form complexes with the inhibitors present. The comparison of the emission, excitation and / or lifetime characteristics of the free lanthanide ions and the complexed lanthanide ions makes it possible to identify and quantify the inhibitors present in the extracted fluid. According to the invention, the inhibitor is detected, and its quantified level, using a time-resolved fluorescence method which is described in particular in the article "Ultrasensitive bioanalytical assays using resolved time fluorescence detection", Pharmacol. Ther. Flight. 66 (2), pp. 207-35, 1995. This is based on the application of a delay, called integration delay, between the excitation of the sample to be analyzed and the measurement of the signal emitted, so as to overcome the fluorescences parasites short life span. This method can be carried out at ambient temperature, in particular using a Cary Eclipse type apparatus from Agilent, as indicated in the Examples. The excitation wavelength may be between 200 and 600 nm and the emission wavelength may be between 300 and 800 nm. The integration time may be between 0.001 and 10 ms, preferably between 0.01 and 5 ms, more preferably between 0.1 and 3 ms. In some cases, the longer the delay, the better the signal-to-noise ratio, which improves the reliability of the measurement. The photon harvesting time can range from 5 to 10 ms, for example. This method can be applied in different ways. It is thus possible to compare the emission intensity of the tested sample with those obtained at different concentrations of inhibitor, to deduce the concentration of the inhibitor in the sample. Alternatively, it is possible to detect several inhibitors in the test sample by measuring the decay rate of the signal emitted by the sample, or half-life, and comparing the values obtained with those known for the different inhibitors. FIGURES FIG. 1 illustrates the excitation spectrum of Tb-DETMP mixtures. FIG. 2 illustrates the fluorescence intensity versus sulfonated PPCA concentration curve. FIG. 3 represents the fluorescence intensity curve. FIG. 4 shows the excitation spectra of 5 Tb-IDOS-DETMP mixtures in Qatar production water. FIG. 5 illustrates the decay curves of Tb-PPCA mixtures sulfonated cyclohexylamine morpholine. Figure 6 illustrates the emission spectra of different concentrations of DOTAGA-labeled F11 inhibitor (Tb). Figure 7 illustrates the emission spectrum of a grafted polyethyleneimine inhibitor DOTA-GA (Eu). Figures 8 and 9 respectively illustrate the excitation spectra of sulfonated Tb-PPCA mixtures with an integration delay of 0.1 ms and 3 ms. The present invention will be better understood in the light of the following examples: The following limiting conditions are given for illustrative purposes only and are not intended to limit the scope of this invention which is defined by the appended claims. EXAMPLES Example 1 - Detection of Complexed Marked DETMP Four solutions of varying concentrations between 0 and 5 ppm were prepared by adding volumes of 0 1000 μl of DETMP solution (calcium sulfate and sulfate inhibitor) to 10 ppm in 2 mL of production water from the Lagrave well, France. A sufficient amount of TbCl3 is then added to give a concentration of 0.5 ppm. Solutions are mixed and measurements made after 5 minutes.
    [0010] The measurements are made in a quartz chamber at room temperature on an Agilent Cary Eclipse (75kW Xenon flash lamp, Czerny-Turner Monochromators, Apui '= 2 ps, 800V PM detector). The delay is set at 0.1 ms and the photon harvest time at 5 ms. The frequency of the lamp is set at 100 Hz. Excitation spectra of the different samples are made between 220 and 400 nm with Δλ = 545 nm. The spectra obtained are shown in FIG. 1. A modification of the intensities and the peak shape on the excitation spectra reflecting a complexation of terbium ions by the DETMP is observed in FIG. This example shows that it is thus possible to detect the DETMP between 0.5 and 5 ppm. EXAMPLE 2 Detection of a Polymer-Labeled Inhibitor by Complexation Eleven solutions of varying concentrations are prepared between 0 and 10 ppm by adding volumes of 0 to 1000 μl of sulfonated PPCA solution (IDOS 150 supplied by REP, which is an inhibitor barium and strontium deposits) at 100 ppm in 2 mL of water. A sufficient amount of TbCl3 is then added to give a concentration of 10 ppm. Solutions are mixed and measurements made after 5 minutes.
    [0011] The measurements are made in a quartz chamber at room temperature on an Agilent Cary Eclipse (75kW Xenon flash lamp, Czerny-Turner Monochromators, Apui '= 2 ps, 800V PM detector). The delay is set at 3 ms and the photon harvest time at 5 ms. The frequency of the lamp is set at 100 Hz. Excitation spectra of the different samples are made between 220 and 250 nm with Δλ = 545 nm. The peak intensities at 225 nm are shown in Table 1 below. Table 1 Intensity concentration at 225 nm Sulfonated PPCA (in (emission at 545 nm) ppm) Time: 3 ms (in pdu) 0.0 1.7 1.0 10.0 2.0 20.0 2.9 28.5 3.8 38.0 4.8 42.5 5.7 48.4 6.5 56.3 7.4 62.1 8.3 68.1 9.1 74.4 The set of resulting points is shown in Figure 2. It can be seen from this Figure that the emission intensity changes clearly with the amount of inhibitor. It is thus possible to easily determine the amount of sulfonated PPCA up to a concentration of less than 10 ppm and with an accuracy of less than 1 ppm.
    [0012] EXAMPLE 3 Detection of a Complexed Styrene Sulfonated Acid / Maleic Acid Copolymer Eleven solutions of variable concentrations are prepared between 0 and 5 ppm by adding volumes of 1000 μl of styrene sulfonic acid / maleic acid copolymer solution, or FL1. (zinc and lead sulphide deposit inhibitor) at 10 ppm in 2 mL of production water from the Lagrave well, France. A sufficient amount of TbCl3 is then added to give a concentration of 10 ppm. Solutions are mixed and measurements made after 5 minutes. The measurements are made in a quartz chamber at room temperature on an Agilent Cary Eclipse (75kW Xenon flash lamp, Czerny-Turner Monochromators, Apui '= 2 ps, 800V PM detector). The delay is set at 3 ms and the photon harvest time at 5 ms. The lamp frequency is set to 100 Hz.
    [0013] Excitation spectra of the different samples are made between 220 and 250 nm with Δλ = 545 nm. Peak intensities at 225 nm are shown in Table 2 below.
    [0014] Table 2 Intensity concentration at 225 nm F11 (in ppm) (emission at 545 nm) Delay: 3 ms (in pdu) 0.00 1.8 0.10 7.0 0.20 11.2 0.29 13.2 0.38 17.8 0.48 19.0 0.91 25.4 1.30 30.8 1.67 30.7 2.00 30.3 3.33 27.1 L The set of resulting points is shown in Figure 3. As can be seen from this figure, the emission intensity changes clearly with the amount of inhibitor. It is thus possible to easily determine the amount of F11 up to a concentration of less than 1 ppm and with an accuracy below 0.1 ppm. Example 4 - Detection of Complexation Marked Deposition Inhibitors in Qatar Water Four solutions containing different deposition inhibitors were prepared by adding volumes of 0 to 20 μl of 100 ppm sulphonated DETMP or PPCA solution in 2 mL of production water from a well located in Qatar. A sufficient amount of TbCl3 is then added to give a concentration of 5 ppm. Solutions are mixed and measurements made after 5 minutes.
    [0015] The measurements are made in a quartz chamber at room temperature on an Agilent Cary Eclipse (75kW Xenon flash lamp, Czerny-Turner Monochromators, Apui '= 2 ps, 800V PM detector). The delay is set at 3 ms and the photon harvest time at 5 ms. The frequency of the lamp is set at 100 Hz. Excitation spectra of the different samples are made between 220 and 280 nm with Δλ = 545 nm. The spectra obtained are shown in FIG. 4. As is apparent from this Figure, the fluorescence intensity is clearly modified by the addition of sulfonated PPCA or DETMP. It is therefore possible to determine concentrations of sulfonated PPCA and DETMP in Qatar production waters at concentrations below 1 ppm. EXAMPLE 5 Detection of Complexation-Marked Corrosion Inhibitors Three solutions containing different corrosion inhibitors are prepared by adding volumes of 0 to 20 μl of 100 ppm cyclohexylamine or morpholine solution in 2 ml of water. A sufficient amount of TbCl3 is then added to give a concentration of 5 ppm. Solutions are mixed and measurements made after 5 minutes.
    [0016] The measurements are made in a quartz chamber at room temperature on an Agilent Cary Eclipse (75kW Xenon flash lamp, Czerny-Turner Monochromators, Apui '= 2 ps, 800V PM detector). The delay is set at 0.015 ms, the harvest time at 10 ms, the step at 0.01 ms. The frequency of the lamp is set at 100 Hz. Life spectra are made with 7 ^ -exc = 270 nm and λ = 545 nm. The curves obtained are modeled by decreasing single or double exponentials. The results are summarized in Table 3 below.
    [0017] Table 3 Solution t1 t2 10 ppm Tb 0.185 10 ppm Tb + 1 ppm 0.112 0.286 cyclohexylamine 10 ppm Tb + 1 ppm morpholine 0.047 0.253 Here we observe the appearance of a second decay rate when an inhibitor is added. Corrosion. This allows their discrimination against free terbium ions and therefore their detection. Example 6 - Detection of a mixture of complexation-labeled deposition and corrosion inhibitors Four solutions containing different corrosion and deposition inhibitors were prepared by adding volumes of 0 to 20 μl of cyclohexylamine solution, morpholine (inhibitors of corrosion) or sulfonated PPCA (deposit inhibitor) at 100 ppm in 2 mL of water. A sufficient amount of TbCl3 is then added to obtain a concentration of 5 ppm. Solutions are mixed and measurements made after 5 minutes. The measurements are made in a quartz chamber at room temperature on an Agilent Cary Eclipse (75kW Xenon flash lamp, Czerny-Turner Monochromators, Apui '= 2 ps, 800V PM detector). The delay is set at 0.015 ms, the harvest time at 10 ms, the step at 0.01 ms. The lamp frequency is set to 100 Hz.
    [0018] Life spectra are made with 7 ^ -exc = 270 nm and λ = 545 nm. The set of curves obtained is grouped in FIG. 5. The curves obtained are modeled by single or double decreasing exponentials, and the results are grouped in Table 4 below. Table 4 Product t1 t2 TbC13 0.185 TbC13 + Sulfonated PPCA 0.185 0.720 TbC13 + Sulfonated PPCA + hexylamine 0.185 0.747 TbC13 + PPCA Sulfonated Morpholine + Hexylamine + 0.185 0.776 Here it is observed that the long component of decay for the three mixtures of deposition inhibitors and corrosion is different for each of the mixtures. This makes it possible to determine the lifetime of each product independently and to separate the contribution in intensity of each of the fluorescences. It is thus possible to know the concentration of a mixture of inhibitors with good accuracy. EXAMPLE 7 Detection of a Styrene-sulfonic Acid / Maleic Acid Copolymer Labeled by Compound Grafting In a 10 ml flask, 5 ml of styrene sulfonic acid / maleic acid copolymer (zinc and lead sulphide deposition inhibitor) are placed, or F11, at 30% by weight. The pH is then adjusted to about 6.3 by adding about 50 μl of 6M HCI. In a second vial of 15 ml, 5 ml of diethylene glycol (DEG) and 40 mg of DOTA-GA anhydride (Chematech Company, France) and 18 μl of diethylenetriamine (DETA) are placed. The pH of this second solution is adjusted to about 7.2 by adding about 30 μl 6M HCI. Both solutions are placed under magnetic stirring for 24 hours. After 24 hours, 101 mg of 1-ethyl-3- (3-dimethylaminopropyl) carbodiimide (EDC) and 170 mg of N-hydroxysuccinimide (NHS) are added to the first flask containing F11. The pH is then adjusted again to 6.3. After 15 minutes, the contents of the two flasks are mixed. The pH is adjusted to 7.2. After 24 hours 20 mg of TbC13.6H20 (Company Nano-H, France) are added and the solution is placed in an oven at 80 ° C. for 24 hours. After cooling to room temperature, the solution is purified on a 10 kDa VIVASPIN® system.
    [0019] Seven solutions containing different concentrations of DOTA-GA labeled inhibitor (Tb) are prepared by adding volumes of 0 to 1000 μl of a 100 ppm inhibitor solution to 1000 2000 μl water volumes, in order to Obtain inhibitor concentrations between 0 and 50 ppm and a total volume of 2 mL. A solution containing 50 ppm TbCl3 is also prepared for reference.
    [0020] A solution of 2 mL of water containing 1 ppm DOTA-GA labeled inhibitor (Tb) is then analyzed. The measurements are carried out at ambient temperature on a Cary Eclipse from the Agilent company (75kW Xenon flash lamp, Czerny-Turner Monochromators, Apui '= 2 ps, PM detector at 800V). The delay is set at 0.1 ms and the photon harvest time at 5 ms. The lamp frequency is set to 100 Hz.
    [0021] A set of emission spectra is produced between 450 and 650 nm with 2 .ex, = 352 nm. The curves obtained are shown in FIG. 6. This figure clearly shows the characteristic emission peaks of terbium at 485, 545, 575 and 620 nm. In addition, an increase in intensity is clearly observed as a function of the amount of labeled inhibitor present in solution. This makes it possible to affirm that it is possible to detect this labeled inhibitor at a concentration of less than 0.75 ppm with good precision. EXAMPLE 8 - Detection of graft-labeled complex polyethyleneimine In a 100 ml flask, 4 6 mL of polyethyleneimine (lead and zinc sulphide deposit inhibitor) at 10% by weight. 29.3 mg of DOTA-GA anhydride (Chematech Company, France) are added as well as a sufficient quantity of distilled water to reach a total volume of 60 ml. The solution is stirred by magnetic stirring for 2 hours. 30.0 mg of EuC13.6H2O (Nano-H Company, France) are then added to the solution prepared. The whole is placed in an oven at 80 ° C for about 12 hours. After cooling to room temperature, the solution is purified on a 10 kDa VIVASPIN® system with a level greater than 1000. A solution of 2 mL of DOTAGA graft inhibitor (Eu) at 1 ppm is prepared.
    [0022] The measurements are carried out at ambient temperature on a Cary Eclipse from the Agilent company (75kW Xenon flash lamp, Czerny-Turner Monochromators, Apui '= 2 ps, PM detector at 800V). The delay is set at 0.1 ms and the photon harvest time at 5 ms. The frequency of the lamp is set at 100 Hz. An emission spectrum of the prepared solution is produced between 550 and 750 nm with λex = 595 nm. The resulting curve is shown in Figure 7.
    [0023] This figure clearly shows the characteristic peaks of europium at 595, 615 and 700 nm. This test shows that it is possible to label inhibitors such as polyethyleneimine with a complex such as DOTA-GA (Eu) and detect them at concentrations below 1 ppm.
    [0024] Example 9 - Study of the variation of the integration time Fifteen solutions of variable concentrations are prepared between 0 and 10 ppm by adding volumes of 0 to 1000 μl of 100 ppm sulphated PPCA solution in 2 ml of water. A sufficient amount of TbCl3 is then added to give a concentration of 10 ppm. Solutions are mixed and measurements made after 5 minutes.
    [0025] The measurements are made in a quartz chamber at room temperature on an Agilent Cary Eclipse (75kW Xenon flash lamp, Czerny-Turner Monochromators, Apui '= 2 ps, 800V PM detector). The photon collection time is fixed at 5 ms. The frequency of the lamp is set at 100 Hz. Excitation spectra of the different samples are made between 220 and 250 nm with Δλ = 545 nm with a delay of 0.1 ms or 3 ms. The spectra obtained are shown in Figures 8 and 9, respectively. Comparing FIGS. 8 and 9, it is noted that the increase in the delay from 0.1 ms to 3 ms makes it possible to very considerably reduce the background noise (passage from an intensity of 200 pdu to about 0), which has the effect of greatly increasing the signal-to-noise ratio and thus allows a much easier detection of the different inhibitors analyzed. As can also be noticed, a longer delay also makes it possible to obtain a better linearity throughout the analysis.
    权利要求:
    Claims (8)
    [0001]
    REVENDICATIONS1. A method of adjusting to a predetermined value the rate of an inhibitor of mineral deposits or corrosion injected into a gas or oil well, comprising the following successive steps: - the labeling of the inhibitor with the aid of a lanthanide, - the detection and quantification of the labeled inhibitor, by time resolved fluorescence, in the fluid extracted from the production well, and - if necessary, the injection into the well of a quantity of additional inhibitor allowing to reach said predetermined value. 15
    [0002]
    2. Method according to claim 1, characterized in that the lanthanide is chosen from: Pr, Nd, Sm, Eu, Tb, Dy, Ho, Er, Tm and Yb, as well as their mixtures and / or alloys, preferably Tb and Eu. 20
    [0003]
    3. Method according to one of claims 1 and 2, characterized in that the inorganic deposit inhibitor is chosen from: - polyphosphates, - organophosphonates, - polycarboxylic acids, - sulfonic acid-functional polymers, especially copolymers of styrene sulfonic acid and maleic acid, polyphosphinocarboxylic acid (PPCA) optionally sulfonated, polyethyleneimine, silicone polymers functionalized with amine groups, and quaternary ammonium-based copolymers. .
    [0004]
    4. Method according to one of claims 1 and 2, characterized in that the corrosion inhibitor is selected from cyclohxylamine, hexylamine, morpholine, octadecylamine, diethylaminoethanol and betaines.
    [0005]
    5. Method according to any one of claims 1 to 4, characterized in that the labeling of the inhibitor is carried out by grafting, on the backbone of the inhibitor, a molecule complexing the lanthanide.
    [0006]
    6. Method according to any one of claims 1 to 4, characterized in that the labeling of the inhibitor is carried out by complexing the lanthanide with the aid of the inhibitor.
    [0007]
    7. Method according to any one of claims 1 to 6, characterized in that the integration time between the excitation of the sample to be analyzed and the measurement of the emitted signal is between 0.001 and 10 ms, preferably between 0.01 and 5 ms, more preferably between 0.1 and 3 ms. 25
    [0008]
    8. Use of the time resolved fluorescence method for detecting and quantifying an inhibitor of mineral deposits or corrosion in a fluid from an oil or gas production well.
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    法律状态:
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    2021-09-10| ST| Notification of lapse|Effective date: 20210805 |
    优先权:
    申请号 | 申请日 | 专利标题
    FR1363287A|FR3015547B1|2013-12-20|2013-12-20|METHOD FOR ADJUSTING THE INHIBITOR RATE IN AN OIL OR GAS WELL|FR1363287A| FR3015547B1|2013-12-20|2013-12-20|METHOD FOR ADJUSTING THE INHIBITOR RATE IN AN OIL OR GAS WELL|
    ARP140104749A| AR098822A1|2013-12-20|2014-12-18|METHOD FOR ADJUSTING THE RATE OF INHIBITORS IN AN OIL OR GAS WELL|
    EP14830834.9A| EP3084119B1|2013-12-20|2014-12-19|Method for adjusting the level of inhibitors in an oil or gas well|
    US15/105,328| US10329879B2|2013-12-20|2014-12-19|Method for adjusting the level of inhibitors in an oil or gas well|
    DK14830834.9T| DK3084119T3|2013-12-20|2014-12-19|PROCEDURE FOR SETTING THE LEVEL OF INHIBITORS IN AN OIL OR GAS CELL|
    PCT/FR2014/053441| WO2015092310A1|2013-12-20|2014-12-19|Method for adjusting the level of inhibitors in an oil or gas well|
    US16/408,824| US10920534B2|2013-12-20|2019-05-10|Method for adjusting the level of inhibitors in an oil or gas well|
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