EP2366868B1 - Method for reducing the injection pressure of a polymer solution in an oil well without shear degradation - Google Patents

Method for reducing the injection pressure of a polymer solution in an oil well without shear degradation Download PDF

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Publication number
EP2366868B1
EP2366868B1 EP11305180.9A EP11305180A EP2366868B1 EP 2366868 B1 EP2366868 B1 EP 2366868B1 EP 11305180 A EP11305180 A EP 11305180A EP 2366868 B1 EP2366868 B1 EP 2366868B1
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European Patent Office
Prior art keywords
pump
well
brake
pressure
injection
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EP11305180.9A
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German (de)
French (fr)
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EP2366868A1 (en
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Philippe Jeronimo
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SPCM SA
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SPCM SA
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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/06—Arrangements for treating drilling fluids outside the borehole
    • E21B21/062—Arrangements for treating drilling fluids outside the borehole by mixing components
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/25—Methods for stimulating production
    • E21B43/26—Methods for stimulating production by forming crevices or fractures
    • E21B43/2607—Surface equipment specially adapted for fracturing operations

Definitions

  • the invention relates to a method for reducing the injection pressure of a water-soluble polymer solution in the oil wells of the same field as a function of their fracturing pressure and without shear of said solution.
  • chokes which are in fact variable-flow valves, regulated or not, which create a pressure drop limiting flow rates and downstream pressures. This is particularly important for water flooding operations where the same line serves various injection wells. Each well having a different fracturing pressure, it is necessary from the same pump to reduce and control the pressure on each well accurately.
  • These materials have become increasingly sophisticated, especially for underwater operations from platforms or FPSOs. They are operated electrically or pneumatically remotely with a gradual opening depending on the angle of rotation.
  • the document US 2009/0242201 A1 describes a method for controlling the polymer concentration and thus the viscosity of the injection solution as a function of the well.
  • a stock solution of polymer is prepared before being distributed by means of a pump to different injection sites. It is only at this stage that the stock solution is diluted with seawater to give the daughter solution.
  • the flow rate of the stock solution is regulated using a second pump, before dilution.
  • the daughter solution obtained after dilution, is distributed and injected into four wells by means of four other individual pumps.
  • Water-soluble polymers of high molecular weight are sensitive to mechanical degradation. This breaks the chains and reduces the viscosity of the injected solution. This reduction in viscosity can occur in any system involving shear: pumps (especially centrifugal pumps), piping, injectors but especially in the choke.
  • pumps especially centrifugal pumps
  • piping especially in the choke.
  • injectors but especially in the choke.
  • US 4,510,397 discloses a positive displacement pump for controlling the flow rate of a polymeric solution. This pump makes it possible to reduce the degradation of the polymer in solution. It is connected to a current generator.
  • one of the solutions is to use a length of the tube of smaller diameter than the pumping piping increasing the speed of passage and thus creating a progressive pressure drop.
  • Potential speeds of up to 10 m have little effect on mechanical degradation, but long piping lengths are required to achieve limited head losses: from 50 to 200 meters on existing installations for 10 bars of load loss .
  • the proposed solution is to replace the choke by a volumetric pump whose flow is controlled.
  • This positive displacement pump works as a motor and the reduction of speed makes it possible to reduce the flow rate as well as the injection pressure.
  • the subject of the invention is a method for reducing the injection pressure of a water-soluble polymer solution from the same injection pump in various oil wells of the same field as a function of the fracturing pressure of each well according to which is intercalated, between the injection pump and each of the wells, a positive displacement main pump, preferably reversible, whose speed is controlled by means of a brake.
  • the industrial pump used as a motor is volumetric and reversible type that is to say that it can operate in pump and motor indifferently, which limits its industrial selection to gear pumps or lobe.
  • gear pumps such as those manufactured for example by the companies Witte Pumps and Technology GmbH or Coreau SA have flow rates ranging up to 200 m 3 / h for body pressures of 300 bar and differential pressures of 200 bar.
  • These pumps are constructed of a variety of materials that can withstand brines injected into oil wells and have dissolved solids quantities of up to 200,000 ppm.
  • the preferred pumps are manufactured in duplex or super duplex and in extreme ceramic applications.
  • These pumps are reversible and it is therefore for a particular well to receive a solution of polymer at a high pressure, for example 120 bar to reduce it from 0 to 50 bar so as to inject it into the well at a pressure of pressure of 70 to 120 bar.
  • This pressure is very variable from one field to another, for example 40 to 250 bar, but on the same field, and for the same injection pump the differential pressure of injection between various wells is most often less than 30 bar, exceptionally 50 bars.
  • the flow per well obviously depends on the type and size of the well. In particular, much smaller amounts of polymers are injected into vertical wells than in horizontal wells.
  • the pump used as a motor will have to be braked so as to reduce the flow and therefore the injection pressure.
  • the type of brake used should be mechanical or electrical by eliminating friction systems that have a limited life.
  • This brake will depend on the conditions of use and the possibilities of dissipation of the heat generated.
  • the well is a subsea well and the brake is in the form of a volumetric pump fed with seawater and connected to the drive shaft of the main displacement pump, the flow rate of the pump volumetric brake serving being regulated by a valve located downstream of said pump whose closure and opening is managed according to the injection pressure decided for each well.
  • a volumetric pump will be chosen as the brake.
  • the motor shaft of the main pump will be connected to another positive displacement pump acting as a brake, for example a gear, the flow rate of which will be regulated by a discharge valve.
  • this pump will be at high pressure, for example 200 bar and its pumping volume to create a maximum pressure drop of 50 bar will be in these conditions less than the main flow.
  • This pump will be supplied with seawater through a filter for example of size 20 microns or two filters in parallel cleaned successively countercurrent with filtered water.
  • the regulation of the assembly will be done by an injection pressure measurement acting directly on the valve closure of the brake pump.
  • the well is a terrestrial well and the brake is an electric brake.
  • a Telma® type electric brake is used, for example, that is to say an eddy current braking system incorporating a cooling by internal ventilation.
  • This system is widely used for braking trucks.
  • the choice of the main pump will be made in these cases at a higher speed to remain within the efficiency range of the Telma® brake at 300 - 500 rpm. It will also be possible to multiply the speed by gears to work at higher speeds that is to say up to 3000 revolutions / minute.
  • the choice of the size of the brake is made by selection in the Valéo® range for example.
  • the injection pressure of the polymer is between 50 and 300 bar and the well fracturing pressure is 0 to 100 bar lower, preferably 0 to 50 bar.
  • the figure 1 shows, the drop in viscosity that can be very important, and whatever the concentration of injected polymer.
  • the polymer solution is injected into the different wells 1, 2 and 3 (P1, P2, P3) from a single injection pump (4) through separate channels (5, 6). , 7).
  • the chokes conventionally present on these pipes are replaced according to the invention by positive displacement pumps (8, 9, 10) whose speed is controlled by a brake not shown.
  • This system makes it possible to control the injection pressure of the polymer solution from the pump (4) at a pressure of, for example, 120 bar, depending on the fracturing pressure of each of the wells, for example from 80 to 120 bars. .
  • FIG 3 schematically a first embodiment of the installation is reproduced which is reproduced on each pipe (5, 6, 7).
  • This type of installation is more particularly used for the underwater extraction of oil.
  • the main positive displacement pump (8) is connected (11) by its shaft engine with a second positive displacement pump (12) supplied via a pipe (13) in which seawater circulates.
  • a discharge valve (14) controlled by a manometer (15) detecting the fracturing pressure of the well into which the polymer solution is to be injected.
  • the discharge valve (14) is more or less closed, thereby slowing down the flow of the main pump (8) by braking its motor shaft by means of the pump ( 12).
  • the configuration illustrated on the figure 4 corresponds to a terrestrial installation.
  • the main pump (8) is no longer braked mechanically by a second positive displacement pump but by means of a brake (16) for example of the Telma® type powered by a battery (17).
  • Braking remains a function of the fracturing pressure detected at the well by means of a manometer (15).
  • the pump shaft is mounted on Telma® brake allowing a variation of 500 to 300 rpm, that is to say 36 to 21 m 3 / h.
  • a discharge valve after the second pump is controlled by the injection pressure on the well and reduces the flow rate so as to brake the main pump from 300 to 200 rpm reducing the flow rate from 100 to 66 m 3 / h on the well with lower fracturing pressure.
  • the pump is fed through two backwash filters and uses the pressure of the brake pump to clean these filters one after the other.
  • the principle of this method can receive various variants and in particular use the power of the main pump to recover electricity via an alternator or a dynamo. It is also possible to use an air compressor as a brake and regulate the pressure by the air leak generated. Those skilled in the art will be able to adapt all the technical methods necessary for this realization.

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  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Fluid Mechanics (AREA)
  • Environmental & Geological Engineering (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Physics & Mathematics (AREA)
  • Mechanical Engineering (AREA)
  • Reciprocating Pumps (AREA)
  • Rotary Pumps (AREA)
  • Injection Moulding Of Plastics Or The Like (AREA)
  • Details Of Reciprocating Pumps (AREA)
  • Lubricants (AREA)
  • Control Of Positive-Displacement Pumps (AREA)

Description

L'invention a pour objet un procédé de réduction de la pression d'injection d'une solution de polymère hydrosoluble dans les puits de pétrole d'un même champ en fonction de leur pression de fracturation et ce, sans cisaillement de ladite solution.The invention relates to a method for reducing the injection pressure of a water-soluble polymer solution in the oil wells of the same field as a function of their fracturing pressure and without shear of said solution.

Dans beaucoup d'opérations dans l'industrie du pétrole, il est nécessaire de réduire la pression des fluides d'une manière différenciée entre plusieurs lignes d'injection.In many operations in the petroleum industry, it is necessary to reduce fluid pressure in a differentiated manner between multiple injection lines.

Cette opération est effectuée avec des duses (anglais : chokes) qui sont en fait des vannes à passage variable, régulées ou non, qui créent une perte de charge limitant les débits et les pressions avals. Ceci est particulièrement important pour les opérations d'injection d'eau (water flooding) où une même ligne dessert divers puits d'injection. Chaque puits ayant une pression de fracturation différente, il est nécessaire à partir d'une même pompe de réduire et contrôler la pression sur chaque puits avec précision. Ces matériels sont devenus de plus en plus sophistiqués, spécialement pour les opérations sous marines à partir de plateformes ou de FPSO. Elles sont manoeuvrées électriquement ou pneumatiquement à distance avec une ouverture progressive en fonction de l'angle de rotation.This operation is performed with chokes, which are in fact variable-flow valves, regulated or not, which create a pressure drop limiting flow rates and downstream pressures. This is particularly important for water flooding operations where the same line serves various injection wells. Each well having a different fracturing pressure, it is necessary from the same pump to reduce and control the pressure on each well accurately. These materials have become increasingly sophisticated, especially for underwater operations from platforms or FPSOs. They are operated electrically or pneumatically remotely with a gradual opening depending on the angle of rotation.

Par ailleurs, la Récupération Assistée du Pétrole s'est développée depuis le premier choc pétrolier en 1973, spécialement aux USA pour augmenter la récupération du pétrole en place. La méthode la plus efficace pour des champs à faible température (<120°C) est l'injection d'une solution visqueuse qui homogénéise la mobilité de l'eau et du pétrole et permet à la fois un meilleur balayage dans la zone de production et une augmentation du volume de celle-ci.In addition, the Assisted Recovery of Petroleum has developed since the first oil crisis in 1973, especially in the US to increase the recovery of oil in place. The most efficient method for low temperature fields (<120 ° C) is the injection of a viscous solution that homogenizes the mobility of water and oil and allows a better sweeping in the production area. and an increase in the volume thereof.

Trois méthodes sont particulièrement utilisées :

  • Injection de polymère à une concentration de 500 à 3000 ppm (typiquement 1000 à 1500 ppm) avec des viscosités variant avec la salinité de l'eau de 5 à 100 cps.
  • Injection d'un polymère et d'un surfactant (SP), le polymère étant aux mêmes concentrations que ci -dessus, le surfactant permettant d'améliorer la mobilisation de l'huile en place.
  • Injection d'un polymère, d'un surfactant et d'un produit alcalin (ASP). Le surfactant et l'alcalin dispersent l'huile dans l'eau injectée et permettent une meilleure extraction. Le polymère est injecté à des concentrations supérieures (2000-3000 ppm) mais sa viscosité est réduite par la présence d'alcalis à des valeurs semblables (5 à 100 cpm).
Three methods are particularly used:
  • Polymer injection at a concentration of 500 to 3000 ppm (typically 1000 to 1500 ppm) with varying viscosities with water salinity of 5 to 100 cps.
  • Injection of a polymer and a surfactant (SP), the polymer being at the same concentrations as above, the surfactant to improve the mobilization of the oil in place.
  • Injection of a polymer, a surfactant and an alkaline product (ASP). The surfactant and the alkali disperse the oil in the injected water and allow a better extraction. The polymer is injected at higher concentrations (2000-3000 ppm) but its viscosity is reduced by the presence of alkalis at similar values (5 to 100 cpm).

Le document US 2009/0242201 A1 décrit un procédé permettant de contrôler la concentration de polymère et donc la viscosité de la solution d'injection en fonction du puits. Dans ce procédé, une solution mère de polymère est préparée avant d'être répartie au moyen d'une pompe vers différents sites d'injection. Ce n'est qu'à ce stade que la solution mère est diluée avec de l'eau de mer pour donner la solution fille. Afin de contrôler la viscosité de la solution fille à injecter dans le puits, le débit de la solution mère est régulé à l'aide d'une deuxième pompe, avant dilution. La solution fille, obtenue après dilution, est répartie et injectée dans quatre puits au moyen de quatre autres pompes individuelles.The document US 2009/0242201 A1 describes a method for controlling the polymer concentration and thus the viscosity of the injection solution as a function of the well. In this process, a stock solution of polymer is prepared before being distributed by means of a pump to different injection sites. It is only at this stage that the stock solution is diluted with seawater to give the daughter solution. In order to control the viscosity of the daughter solution to be injected into the well, the flow rate of the stock solution is regulated using a second pump, before dilution. The daughter solution, obtained after dilution, is distributed and injected into four wells by means of four other individual pumps.

Les polymères hydrosolubles de hauts poids moléculaires sont sensibles à la dégradation mécanique. Celle-ci rompt les chaines et réduit la viscosité de la solution injectée. Cette réduction de viscosité peut se produire dans tout système comportant un cisaillement : pompes (spécialement les pompes centrifuges), tuyauteries, injecteurs mais surtout dans les duses. A cet égard, le document US 4,510,397 décrit une pompe volumétrique permettant de contrôler le débit d'une solution polymérique. Cette pompe permet de diminuer la dégradation du polymère en solution. Elle est reliée à un générateur de courant.Water-soluble polymers of high molecular weight are sensitive to mechanical degradation. This breaks the chains and reduces the viscosity of the injected solution. This reduction in viscosity can occur in any system involving shear: pumps (especially centrifugal pumps), piping, injectors but especially in the choke. In this respect, the document US 4,510,397 discloses a positive displacement pump for controlling the flow rate of a polymeric solution. This pump makes it possible to reduce the degradation of the polymer in solution. It is connected to a current generator.

Il est donc nécessaire de trouver une solution réduisant le cisaillement et améliorant l'efficacité du polymère.It is therefore necessary to find a solution reducing shear and improving the effectiveness of the polymer.

Sur les petits puits de pétrole, une des solutions est d'utiliser une longueur du tube de diamètre inférieur à la tuyauterie de pompage augmentant la vitesse de passage et donc créant une perte de charge progressive. Les vitesses potentielles jusqu'à 10 m seconde ont peu d'effet sur la dégradation mécanique mais il faut de grandes longueurs de tuyauteries pour obtenir des pertes de charge limitées: de 50 à 200 mètres sur des installations existantes pour 10 bars de perte de charge. De plus, il est nécessaire de changer la longueur de tuyauterie durant la vie du champ pour adapter progressivement la pression d'injection à la pression de champ sans créer de fracturation.On small oil wells, one of the solutions is to use a length of the tube of smaller diameter than the pumping piping increasing the speed of passage and thus creating a progressive pressure drop. Potential speeds of up to 10 m have little effect on mechanical degradation, but long piping lengths are required to achieve limited head losses: from 50 to 200 meters on existing installations for 10 bars of load loss . In addition, it is necessary to change the length of piping during the life of the field to gradually adjust the injection pressure to the field pressure without creating fracturing.

Il n'existe pas, à ce jour, de méthode de réduction de pression entre 0 et 50 bars sans cisaillement.To date, there is no method for reducing pressure between 0 and 50 bar without shearing.

La solution proposée est de remplacer la duse par une pompe volumétrique dont on contrôle le débit. Cette pompe volumétrique travaille comme un moteur et la réduction de vitesse permet de réduire le débit ainsi que la pression d'injection. Il faut pour cela utiliser un système de frein pour contrôler la vitesse de la pompe volumétrique.The proposed solution is to replace the choke by a volumetric pump whose flow is controlled. This positive displacement pump works as a motor and the reduction of speed makes it possible to reduce the flow rate as well as the injection pressure. This requires the use of a brake system to control the speed of the positive displacement pump.

Plus précisément, l'invention a pour objet un procédé de réduction de la pression d'injection d'une solution de polymère hydrosoluble à partir d'une même pompe d'injection dans divers puits de pétrole d'un même champs en fonction de la pression de fracturation de chaque puits selon lequel on intercale, entre la pompe d'injection et chacun des puits, une pompe volumétrique principale, avantageusement réversible, dont on contrôle la vitesse au moyen d'un frein.More specifically, the subject of the invention is a method for reducing the injection pressure of a water-soluble polymer solution from the same injection pump in various oil wells of the same field as a function of the fracturing pressure of each well according to which is intercalated, between the injection pump and each of the wells, a positive displacement main pump, preferably reversible, whose speed is controlled by means of a brake.

Selon une caractéristique essentielle de l'invention, la pompe industrielle utilisée comme moteur est de type volumétrique et réversible c'est-à-dire qu'elle peut fonctionner en pompe et en moteur indifféremment, ce qui limite sa sélection industrielle aux pompes à engrenage ou à lobe.According to an essential characteristic of the invention, the industrial pump used as a motor is volumetric and reversible type that is to say that it can operate in pump and motor indifferently, which limits its industrial selection to gear pumps or lobe.

En pratique, les pompes à engrenage, telles que celle fabriquées par exemple par les sociétés Witte pumps and technology Gmbh ou encore Coreau SA ont des débits allant en standard jusqu'à 200 m3/h pour des pressions de corps de 300 bars et des pressions différentielles de 200 bars.In practice, the gear pumps, such as those manufactured for example by the companies Witte Pumps and Technology GmbH or Coreau SA have flow rates ranging up to 200 m 3 / h for body pressures of 300 bar and differential pressures of 200 bar.

Ces pompes sont construites en divers matériaux pouvant résister aux saumures injectées dans les puits de pétrole et ayant des quantités de solides dissous allant jusqu'à 200 000 ppm. Les pompes préférées sont fabriquées en duplex ou super duplex et dans les applications extrêmes en céramique.These pumps are constructed of a variety of materials that can withstand brines injected into oil wells and have dissolved solids quantities of up to 200,000 ppm. The preferred pumps are manufactured in duplex or super duplex and in extreme ceramic applications.

Ces pompes sont réversibles et il s'agit donc pour un puits particulier de recevoir une solution de polymère à une pression élevée, par exemple 120 bars pour réduire celle-ci de 0 à 50 bars de manière à l'injecter dans le puits à une pression de 70 à 120 bars.These pumps are reversible and it is therefore for a particular well to receive a solution of polymer at a high pressure, for example 120 bar to reduce it from 0 to 50 bar so as to inject it into the well at a pressure of pressure of 70 to 120 bar.

Cette pression est très variable d'un champ à un autre par exemple 40 à 250 bars mais sur un même champ, et pour une même pompe d'injection la pression différentielle d'injection entre divers puits est le plus souvent inférieure à 30 bars, exceptionnellement 50 bars.This pressure is very variable from one field to another, for example 40 to 250 bar, but on the same field, and for the same injection pump the differential pressure of injection between various wells is most often less than 30 bar, exceptionally 50 bars.

Le débit par puits dépend évidemment du type et de la taille du puits. En particulier, on injecte dans les puits verticaux des quantités de polymères beaucoup moins importantes que dans les puits horizontaux.The flow per well obviously depends on the type and size of the well. In particular, much smaller amounts of polymers are injected into vertical wells than in horizontal wells.

En moyenne, on injecte dans un puits vertical 10 à 40 m3/h de solution de polymère et dans un puits horizontal, 50 à 300 m3/h.On average, 10 to 40 m 3 / h of polymer solution are injected into a vertical well and 50 to 300 m 3 / h into a horizontal well.

La pompe à engrenage sera choisie en fonction :

  • Du débit maximum prévu de l'injection
  • La pression amont qui est la pression maximum de la pompe d'injection.
  • Le différentiel de pression entre les puits alimentés par cette pompe.
  • La composition de la saumure qui déterminera le matériau à utiliser pour le corps, les rotors, les paliers, les joints, les garnitures.
  • La longévité de la pompe qui déterminera sa vitesse de rotation, en particulier, les vitesses de rotation seront limitées pour réduire au minimum l'entretien dans les applications sous-marines.
The gear pump will be selected according to:
  • The maximum expected flow rate of the injection
  • The upstream pressure which is the maximum pressure of the injection pump.
  • The pressure differential between the wells fed by this pump.
  • The composition of the brine that will determine the material to be used for the body, rotors, bearings, seals, gaskets.
  • The longevity of the pump which will determine its rotational speed, in particular, rotational speeds will be limited to minimize maintenance in subsea applications.

La pompe utilisée comme moteur devra être freinée de manière à réduire le débit et donc la pression d'injection.The pump used as a motor will have to be braked so as to reduce the flow and therefore the injection pressure.

Le type de frein utilisé devra être mécanique ou électrique en éliminant les systèmes à frottement qui ont une longévité limitée.The type of brake used should be mechanical or electrical by eliminating friction systems that have a limited life.

La sélection de ce frein dépendra des conditions d'utilisation et des possibilités de dissipation de la chaleur générée.The selection of this brake will depend on the conditions of use and the possibilities of dissipation of the heat generated.

Dans un premier mode de réalisation, le puits est un puits sous marin et le frein se présente sous la forme d'une pompe volumétrique alimentée en eau de mer et connectée à l'arbre moteur de la pompe volumétrique principale, le débit de la pompe volumétrique servant de frein étant régulé par une vanne située en aval de ladite pompe dont la fermeture et l'ouverture est gérée en fonction de la pression d'injection décidée pour chaque puits.In a first embodiment, the well is a subsea well and the brake is in the form of a volumetric pump fed with seawater and connected to the drive shaft of the main displacement pump, the flow rate of the pump volumetric brake serving being regulated by a valve located downstream of said pump whose closure and opening is managed according to the injection pressure decided for each well.

Plus précisément, en conditions sous marines les quantités d'eau de refroidissement sont illimitées. Dans ce cas, on choisira une pompe volumétrique comme frein. L'arbre moteur de la pompe principale sera connecté à une autre pompe volumétrique servant de frein, par exemple à engrenage, dont le débit sera régulé par une vanne de décharge. Pour limiter la taille, cette pompe sera à pression élevée, par exemple 200 bars et son volume de pompage pour créer une perte de charge maximum de 50 bars sera dans ces conditions inférieur au débit principal. Cette pompe sera alimentée en eau de mer par l'intermédiaire d'un filtre par exemple de taille 20 microns ou deux filtres en parallèle nettoyés successivement à contrecourant par de l'eau filtrée.More specifically, in underwater conditions the amounts of cooling water are unlimited. In this case, a volumetric pump will be chosen as the brake. The motor shaft of the main pump will be connected to another positive displacement pump acting as a brake, for example a gear, the flow rate of which will be regulated by a discharge valve. To limit the size, this pump will be at high pressure, for example 200 bar and its pumping volume to create a maximum pressure drop of 50 bar will be in these conditions less than the main flow. This pump will be supplied with seawater through a filter for example of size 20 microns or two filters in parallel cleaned successively countercurrent with filtered water.

La régulation de l'ensemble se fera par une mesure de pression à l'injection agissant directement sur la fermeture de vanne de la pompe frein.The regulation of the assembly will be done by an injection pressure measurement acting directly on the valve closure of the brake pump.

Evidemment d'autres types de pompes volumétriques peuvent être utilisés comme frein et en particulier des pompes non réversibles: pompes à piston, pompes types Moineau haute pression...Obviously other types of positive displacement pumps can be used as a brake and in particular non-reversible pumps: piston pumps, high pressure spindle pumps ...

Dans un second mode de réalisation, le puits est un puits terrestre et le frein est un frein électrique.In a second embodiment, the well is a terrestrial well and the brake is an electric brake.

Plus précisément, en conditions terrestres, dans la plupart des cas, les conditions locales ne permettent pas d'avoir accès à des quantités d'eau suffisantes permettant d'utiliser un frein par pompe. Dans ce cas, on utilise un frein électrique type Telma®, par exemple, c'est-à-dire un système de freinage à courants de Foucault intégrant un refroidissement par ventilation interne.Specifically, in terrestrial conditions, in most cases, local conditions do not allow access to sufficient quantities of water to use a brake pump. In this case, a Telma® type electric brake is used, for example, that is to say an eddy current braking system incorporating a cooling by internal ventilation.

Ce système est largement utilisé pour le freinage des camions.This system is widely used for braking trucks.

Le choix de la pompe principale se fera dans ces cas à une vitesse supérieure pour rester dans la plage d'efficacité du frein Telma® à 300 - 500 tours minute. Il sera possible aussi de multiplier la vitesse par des engrenages pour travailler à des vitesses plus élevées c'est-à-dire jusqu'à 3000 tours/minute. Le choix de la taille du frein se fait par sélection dans la gamme Valéo® par exemple.The choice of the main pump will be made in these cases at a higher speed to remain within the efficiency range of the Telma® brake at 300 - 500 rpm. It will also be possible to multiply the speed by gears to work at higher speeds that is to say up to 3000 revolutions / minute. The choice of the size of the brake is made by selection in the Valéo® range for example.

Selon l'invention, la pression d'injection du polymère est comprise entre 50 et 300 bars et la pression de fracturation des puits est de 0 à 100 bars inférieure, préférentiellement de 0 à 50 bars.According to the invention, the injection pressure of the polymer is between 50 and 300 bar and the well fracturing pressure is 0 to 100 bar lower, preferably 0 to 50 bar.

L'invention et les avantages qui en découlent ressortiront bien des exemples de réalisation suivants, à l'appui des figures annexées.

  • La figure 1 est une courbe montrant l'impact de la perte de viscosité d'une solution de polymère en fonction du cisaillement dans une duse Cameron® de débit 100 m3/h.
  • La figure 2 est une représentation schématique de principe d'une installation mettant en oeuvre le procédé de l'invention.
  • La figure 3 est une représentation schématique d'une installation mettant en oeuvre le procédé de l'invention selon un premier mode de réalisation.
  • La figure 4 est une représentation schématique d'une installation mettant en oeuvre le procédé de l'invention selon un second mode de réalisation.
The invention and the advantages resulting therefrom will emerge from the following exemplary embodiments, in support of the appended figures.
  • The figure 1 is a graph showing the impact of viscosity loss of a polymer solution as a function of shear in a Cameron® flow dome 100 m 3 / h.
  • The figure 2 is a schematic representation of a principle of an installation implementing the method of the invention.
  • The figure 3 is a schematic representation of an installation implementing the method of the invention according to a first embodiment.
  • The figure 4 is a schematic representation of an installation implementing the method of the invention according to a second embodiment.

La figure 1 montre, la chute de viscosité qui peut être très importante, et ce, quelle que soit la concentration de polymère injectée.The figure 1 shows, the drop in viscosity that can be very important, and whatever the concentration of injected polymer.

Sur la figure 2, on a représenté le principe général de l'installation mettant en oeuvre le procédé. Pour l'essentiel, la solution de polymère est injectée dans les différents puits 1, 2 et 3 (P1, P2, P3) à partir d'une pompe d'injection unique (4) par le biais de canalisations distinctes (5, 6, 7). Les duses présentes classiquement sur ces canalisations sont remplacées selon l'invention par des pompes volumétriques (8, 9, 10) dont la vitesse est contrôlée par un frein non représenté. Ce système permet de contrôler la pression d'injection de la solution de polymère à partir de la pompe (4) à une pression par exemple de 120 bars, en fonction de la pression de fracturation de chacun des puits par exemple de 80 à 120 bars.On the figure 2 the general principle of the installation implementing the method is represented. Essentially, the polymer solution is injected into the different wells 1, 2 and 3 (P1, P2, P3) from a single injection pump (4) through separate channels (5, 6). , 7). The chokes conventionally present on these pipes are replaced according to the invention by positive displacement pumps (8, 9, 10) whose speed is controlled by a brake not shown. This system makes it possible to control the injection pressure of the polymer solution from the pump (4) at a pressure of, for example, 120 bar, depending on the fracturing pressure of each of the wells, for example from 80 to 120 bars. .

Sur la figure 3, on a représenté schématiquement un premier mode de réalisation de l'installation qui est reproduit sur chaque canalisation (5, 6, 7). Ce type d'installation est plus particulièrement utilisé pour l'extraction sous marine de pétrole. Dans cette hypothèse, la pompe volumétrique principale (8) est connectée (11) par son arbre moteur à une seconde pompe volumétrique (12) alimentée par le biais d'une canalisation (13) dans laquelle circule de l'eau de mer. En aval de la pompe (12) est située une vanne de décharge (14) controlée par un manomètre (15) détectant la pression de fracturation du puits dans lequel doit être injectée la solution de polymère. En fonction de la pression de fracturation détéctée, la vanne de décharge (14) est plus ou moins fermée, ce qui permet ainsi de ralentir le débit de la pompe principale (8) par freinage de son arbre moteur par le biais de la pompe (12).On the figure 3 schematically a first embodiment of the installation is reproduced which is reproduced on each pipe (5, 6, 7). This type of installation is more particularly used for the underwater extraction of oil. In this case, the main positive displacement pump (8) is connected (11) by its shaft engine with a second positive displacement pump (12) supplied via a pipe (13) in which seawater circulates. Downstream of the pump (12) is located a discharge valve (14) controlled by a manometer (15) detecting the fracturing pressure of the well into which the polymer solution is to be injected. Depending on the fracturing pressure detected, the discharge valve (14) is more or less closed, thereby slowing down the flow of the main pump (8) by braking its motor shaft by means of the pump ( 12).

La configuration illustrée sur la figure 4 correspond à une installation terrestre. Dans ce cas, la pompe principale (8) n'est plus freinée mécaniquement par une seconde pompe volumétrique mais au moyen d'un frein (16) par exemple du type Telma® alimenté par une batterie (17). Le freinage reste fonction de la pression de fracturation détectée au niveau du puits au moyen d'un manomètre (15).The configuration illustrated on the figure 4 corresponds to a terrestrial installation. In this case, the main pump (8) is no longer braked mechanically by a second positive displacement pump but by means of a brake (16) for example of the Telma® type powered by a battery (17). Braking remains a function of the fracturing pressure detected at the well by means of a manometer (15).

Exemple 1 : Example 1

Un champ sur terre a les caractéristiques suivantes :

  • Nombre de puits d'injection : 12
  • Types de puits : verticaux
  • Saumure injectée : 12 000 ppm de solide dissous
  • H2S : 15 ppm
  • Température 55°C
  • Débit maximum par puits prévu 32m3/h
  • Pression de la pompe d'injection 110 bars
  • Pression d'injection du puits à pression plus faible : 80 bars
  • Concentration du polymère 900 ppm (Polyacrylamide type 3230S à 30 % d'anionicité et de poids moléculaire 20 moles)
  • Viscosité de pompage 12,6 cps.
A field on earth has the following characteristics:
  • Number of injection wells: 12
  • Well types: vertical
  • Injected brine: 12,000 ppm of dissolved solids
  • H 2 S: 15 ppm
  • Temperature 55 ° C
  • Maximum flow per well planned 32m 3 / h
  • Pressure of the injection pump 110 bars
  • Injection pressure of the lower pressure well: 80 bar
  • Concentration of the polymer 900 ppm (polyacrylamide type 3230S at 30% anionicity and molecular weight 20 moles)
  • Viscosity of pumping 12.6 cps.

Dans ce cas, la réduction de pression sera constituée de pompes à engrenage :

  • Pression du corps : 150 bars
  • Construction Duplex
  • Débit maximum : 35m3/h
  • Cylindrée de la pompe : 2 litres
  • Vitesse maximum : 500 tours minute
In this case, the pressure reduction will consist of gear pumps:
  • Body pressure: 150 bar
  • Duplex Construction
  • Maximum flow: 35m 3 / h
  • Displacement of the pump: 2 liters
  • Maximum speed: 500 rpm

L'arbre de la pompe est monté sur frein Telma® permettant une variation de 500 à 300 tours minute, c'est-à-dire de 36 à 21 m3/h.The pump shaft is mounted on Telma® brake allowing a variation of 500 to 300 rpm, that is to say 36 to 21 m 3 / h.

La prise d'échantillon d'une solution de polymère avec une perte de charge de 40 bars donnera les résultats suivants :

  • Viscosité avant la pompe : 12,6 cps (Brookfield Grpm)
  • Viscosité après la pompe : 11,4 cps
Taking a sample of a polymer solution with a pressure drop of 40 bar will give the following results:
  • Viscosity before the pump: 12.6 cps (Brookfield Grpm)
  • Viscosity after the pump: 11.4 cps

Dans le cas d'utilisation d'une duse à perte de charge 40 bars, la viscosité serait de l'ordre de 5 cps réduisant fortement l'effet de récupération assistée.In the case of using a choke with a pressure drop of 40 bars, the viscosity would be of the order of 5 cps, greatly reducing the effect of enhanced recovery.

Exemple 2 : Example 2

Dans une application sous marine, le champ à les caractéristiques suivantes :

  • Nombre de puits injecteurs: 4
  • Type de puits : horizontaux
  • Saumure injectée : 50 000 ppm de solide dissous
  • H2S : 40 ppm
  • Température d'eau d'injection en fond de mer 45°C
  • Débit maximum par puits : 100 m3/h
  • Pression maximum d'injection au niveau de la duse : 120 bars
  • Pression minimum d'injection : 90 bars pour le puits de pression de fracturation la plus faible.
In a submarine application, the field has the following characteristics:
  • Number of injection wells: 4
  • Well type: horizontal
  • Injected brine: 50,000 ppm of dissolved solids
  • H 2 S: 40 ppm
  • Injection water temperature in seafloor 45 ° C
  • Maximum flow per well: 100 m 3 / h
  • Maximum injection pressure at the choke level: 120 bar
  • Minimum injection pressure: 90 bars for the lowest fracturing pressure well.

Dans ce cas, la pompe à engrenage utilisée comme moteur aura les caractéristiques suivantes :

  • Pression de corps : 200 bars
  • Construction Duplex
  • Débit maximum : 110 m3/h
  • Cylindrée de la pompe : 5,5 litres
  • Vitesse maximum de la pompe : 300 tours minute
In this case, the gear pump used as the motor will have the following characteristics:
  • Body pressure: 200 bar
  • Duplex Construction
  • Maximum flow: 110 m 3 / h
  • Displacement of the pump: 5.5 liters
  • Maximum speed of the pump: 300 rpm

L'arbre de la pompe est solidarisé avec une autre pompe à engrenage de caractéristiques suivantes :

  • Pression de calcul : 200 bars
  • Débit : 60 m3/h
  • Cylindrée : 2 litres
  • Construction super duplex
  • Vitesse de rotation maximum : 500 tours minute
The pump shaft is secured to another gear pump with the following characteristics:
  • Calculation pressure: 200 bar
  • Flow rate: 60 m 3 / h
  • Cylinder capacity: 2 liters
  • Super duplex construction
  • Maximum rotation speed: 500 rpm

Une vanne de décharge après la seconde pompe est contrôlée par la pression d'injection sur le puits et permet de réduire le débit de manière à freiner la pompe principale de 300 à 200 tours minute réduisant le débit de 100 à 66 m3/h sur le puits à plus faible pression de fracturation.A discharge valve after the second pump is controlled by the injection pressure on the well and reduces the flow rate so as to brake the main pump from 300 to 200 rpm reducing the flow rate from 100 to 66 m 3 / h on the well with lower fracturing pressure.

La pompe est alimentée à travers deux filtres à décolmatage à contre courant et utilisant la pression de la pompe frein pour le nettoyage de ces filtres l'un après l'autre.The pump is fed through two backwash filters and uses the pressure of the brake pump to clean these filters one after the other.

Le principe de ce procédé peut recevoir diverses variantes et en particulier utiliser la puissance de la pompe principale pour récupérer de l'électricité par l'intermédiaire d'un alternateur ou d'une dynamo. Il est possible aussi d'utiliser un compresseur à air comme frein et réguler la pression par la fuite d'air engendrée.
L'homme de l'art sera capable d'adapter toutes les méthodes techniques nécessaires à cette réalisation.The principle of this method can receive various variants and in particular use the power of the main pump to recover electricity via an alternator or a dynamo. It is also possible to use an air compressor as a brake and regulate the pressure by the air leak generated.
Those skilled in the art will be able to adapt all the technical methods necessary for this realization.

Claims (9)

  1. A process for reducing the pressure for injecting a solution of water-soluble polymer from a given injection pump (4) into various oil wells in a given field as a function of the fracturation pressure for each well according to which, between the injection pump (4) and each well, a main volumetric pump (8, 9 10) working as an engine is placed, whose rate is controlled using a brake.
  2. The process according to claim 1, wherein the main volumetric pump is reversible.
  3. The process according to claim 1, wherein the volumetric pump is a gear pump.
  4. The process according to claim 1, wherein the well is an offshore well and the brake is in the form of a volumetric pump (12) fed with sea water and connected (11) to the motor shaft of the main volumetric pump (8, 9, 10), the flow rate of the volumetric pump (12) serving as brake being regulated by a valve (14) located downstream of said pump, whose closing and opening is managed as a function of the injection pressure determined for each well.
  5. The process according to claim 4, wherein the brake is in the form of a reversible volumetric gear pump.
  6. The process according to claim 4, wherein the brake is in the form of an irreversible piston pump.
  7. The process according to claim 1, wherein the well is a land well and the brake is an electric brake.
  8. The process according to claim 7, wherein the electric brake is an Eddy current braking system integrating cooling by internal ventilation.
  9. The process according to claim 1, wherein polymer injection pressure is from 50 to 300 bars and the fracturation pressure of the well is from 0 to 100 bars lower.
EP11305180.9A 2010-03-16 2011-02-22 Method for reducing the injection pressure of a polymer solution in an oil well without shear degradation Not-in-force EP2366868B1 (en)

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
FR1051847A FR2957629B1 (en) 2010-03-16 2010-03-16 METHOD FOR REDUCING THE INJECTION PRESSURE OF A POLYMER SOLUTION IN A SHEAR-FREE PETROLEUM WELL OF SAID SOLUTION

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EP (1) EP2366868B1 (en)
BR (1) BRPI1100232B1 (en)
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MX (1) MX2011002672A (en)

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Publication number Priority date Publication date Assignee Title
FR3014475B1 (en) * 2013-12-11 2019-06-21 Total S.A. INJECTION OF A FLUID IN A HYDROCARBON RESERVOIR
FR3014474B1 (en) * 2013-12-11 2015-12-18 Total Sa BRAKING A FLUID IN A HYDROCARBON RESERVOIR
SG10201806341TA (en) * 2014-01-24 2018-08-30 Cameron Tech Ltd Systems and methods for polymer degradation reduction
FR3026773B1 (en) * 2014-10-01 2019-03-29 S.P.C.M. Sa INJECTION PRESSURE CONTROL APPARATUS IN THE ASSISTED RECOVERY OF OFFSHORE OIL
US10030497B2 (en) 2015-02-10 2018-07-24 Statoil Gulf Services LLC Method of acquiring information of hydraulic fracture geometry for evaluating and optimizing well spacing for multi-well pad
US9988900B2 (en) 2015-06-30 2018-06-05 Statoil Gulf Services LLC Method of geometric evaluation of hydraulic fractures by using pressure changes

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US3985468A (en) * 1974-12-24 1976-10-12 The Garrett Corporation Gas turbine fuel delivery system
US4204574A (en) * 1977-09-22 1980-05-27 Conoco, Inc. Low shear polymer injection method with ratio control between wells
US4535844A (en) * 1983-07-20 1985-08-20 Marathon Oil Company Method of using polymer flow control apparatus
US4510397A (en) * 1983-07-20 1985-04-09 Marathon Oil Company Polymer flow control apparatus
US7713032B2 (en) * 2005-08-02 2010-05-11 Davis Sr Albert Hamilton High pressure tide actuated fluid pump
US7703328B2 (en) * 2006-05-18 2010-04-27 Baker Hughes Incorporated Pressure sensor utilizing a low thermal expansion material
US7775040B2 (en) * 2006-11-08 2010-08-17 Caterpillar Inc Bidirectional hydraulic transformer
US7928040B2 (en) * 2007-01-23 2011-04-19 Halliburton Energy Services, Inc. Compositions and methods for breaking a viscosity increasing polymer at very low temperature used in downhole well applications
US20090242201A1 (en) * 2007-06-25 2009-10-01 Jorgen Van Beurden System and method for polymer distribution to well sites
FR2922256B1 (en) * 2007-10-12 2010-03-12 Spcm Sa INSTALLATION FOR THE ASSISTED RECOVERY OF OIL USING WATER-SOLUBLE POLYMERS, METHOD USING THE INSTALLATION

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FR2957629B1 (en) 2012-04-06
BRPI1100232A2 (en) 2015-07-07
MX2011002672A (en) 2011-09-21
US8807222B2 (en) 2014-08-19
US20110226480A1 (en) 2011-09-22
BRPI1100232B1 (en) 2020-11-24
FR2957629A1 (en) 2011-09-23

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