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  • 专利说明
  • 权利要求
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    • 专利摘要:
    Injection pressure control apparatus for a polymeric aqueous solution at the head of subsea oil well, consisting of a linear pressure reducer in the form of a tube connected in series to the main injection pipe suitable for to absorb the majority of the pressure loss and a choke able to be adjusted to allow a pressure control between 0 and 10 bars. Process for assisted oil recovery in offshore by injection of an aqueous polymeric solution using the apparatus.
    公开号:FR3026773A1
    申请号:FR1459378
    申请日:2014-10-01
    公开日:2016-04-08
    发明作者:Pascal Remy；Emmanuel Pich
    申请人:SPCM SA；
    IPC主号:
    专利说明:

    [0001] INJECTION PRESSURE CONTROL APPARATUS IN THE ASSISTED RECOVERY OF OFFSHORE OIL The Enhanced Oil Recovery (EOR) which was specially industrialized in the United States between 1973, the date of the first oil shock, and 1986, the date of the collapse of the oil price at $ 10 a barrel, was put back on the agenda in the early 2000s when the price of oil exceeded $ 40 a barrel. With a current cost of $ 100 a barrel, enhanced oil recovery with the use of water-soluble polymers, which allows an increase in yield of 10% to 20% of additional in-place reserves, has become a technique of choice. However, its implementation on major oilfields faces some technical problems that are solved gradually.
    [0002] One of the materials that allowed this development is the PSU (Polymer Slicing Unit) described in patent EP2203245. These types of water-soluble polymers are very difficult to disperse because of a sticking effect and agglomeration giving gels or "fish eyes" (very long fish to dissolve). These gels can not be injected into formations without damage. The PSU provides both excellent dispersion and high dissolution concentration, reducing the sizes of dissolving tanks and high pressure pumps, which are a major part of the investment required. The second problem is the mechanical degradation of the polymer. Usually, on an oil field, a single water injection pump feeds several wells. But because of the heterogeneity of the fields, the injection pressures are different from one well to another. For this, one installs at the head of wells a control valve or pressure regulator called choke. The polymer solution can not pass through this choke without a degradation substantially proportional to the pressure drop. Approximately, a pressure drop of 20 bar will degrade the viscosity by 20%. A pressure drop of 50 bar will degrade the viscosity by 50%. Obviously these degradations are dependent on the type of polymer, the viscosity, the concentration of the dissolution brine composition, the temperature. Only pilot tests make it possible to predict the extent of the degradation.35 To remedy this problem, various solutions have been used: Usually, the mother solution prepared at a concentration of 10 to 20 gr / liter is pumped by a high triplex pump. pressure at the wellhead, after the choke, before a static mixer. This system requires many pumps (one per well) and many pipelines, which increases the cost of installation. Another solution is to create a solution at the final concentration (500 to 3000 ppm) and inject it into each well via a linear pressure reducer as described in US patent 8607869.
    [0003] This linear pressure reducer is modular and allows using 3 to 6 lengths of tubes separated by 4-way valves to adjust the pressure with an accuracy of 1 to 5 bar, this can be done manually or via a programmable automaton. It is in the form of a box where the stainless steel tube windings can be activated or deactivated to obtain the required pressure.
    [0004] From the technical point of view, the flow of a polymer solution in a tube does not cause degradation or very low degradation of the polymer to a certain speed depending on the diameter of the tube, the viscosity, the salinity of the solution and which can be determined by experience.
    [0005] The pressure drop changes as a function of the flow rate of the polymer solution in the tube, depending on the flow rate as shown in FIGS. 1 and 2. In other words, the polymer is more or less degraded as a function of the speed of the polymer. flow as shown in Figure 3.
    [0006] Usually, the degradation depends on the speed and diameter of the tube. It is considered that a pressure drop of 1 bar over 10 meters leads to an acceptable degradation. However, due to the composition of the brine, the type and the concentration of the polymer, the temperature, preliminary tests make it possible to optimize the diameter and the length of the tube constituting a linear choke. In the case mentioned in Figures 1 to 3, and for a given diameter of 1 inch (2.54 cm), so that the pressure drop is less than or equal to 1 bar over 10 meters, it will be necessary that the speed of flow does not exceed approximately 7.5 m / s, and the flow rate does not exceed 13 m3 / h.
    [0007] Normally, standard chokes can be used to adjust the pressure over a pressure drop range of 0 to 50 bar, which corresponds to the use of a linear pressure reducer of approximately 500 meters.
    [0008] A linear pressure reducer as described in US8607869 works very well when used on the surface because it is directly accessible for control and maintenance operations. Liquid, electrical or hydraulic connections become extremely important when a high degree of reliability is desired.
    [0009] But this type of device becomes very complex when it is to be adapted to underwater applications, in particular as regards the replacement of valves, coils, measuring devices, control of valve openings, surface connections and strong maintenance depending on the case, by divers or robots.
    [0010] Extrapolated to an underwater installation, this type of device entails additional constraints inherent in its technology (control and measurement devices, confirmation of valve openings, measurement of flow and pressure, connectable modules for maintenance, housings electric, umbilical, ...).
    [0011] The object of the invention is therefore to simplify the system so as to give it the robustness and simplicity necessary for underwater use. Subsea production fields have quite a different architecture from terrestrial fields. They are treated from platforms or boats (FPSO) (Figure 4). The water injection or polymer solution policies are very different depending on the operating company. The simplest method is to have one injection tube (riser) per well. In this configuration, dilution of the stock solution is by injection into the high pressure tube after the surface choke installed on the boat or platform. The diameter of these transport tubes is generally of the order of 10 inches (25.4 cm), which does not generate significant pressure drop. But for larger fields, most often, each FPSO or platform descends several risers to manifolds that distribute the flow over several wells via chokes to adjust the injection pressure for each well.
    [0012] This system is totally penalizing for the polymer solutions because from a pressure drop in the choke of 10 to 15 bars, the polymers are degraded significantly. The loss of efficiency of the enhanced oil recovery process due to the degradation of the polymer prior to injection into the well must then be compensated for by an increased polymer concentration which, over 5 to 10 year operating periods, represents an extremely high cost. The invention consists in inserting a pressure reducer upstream or downstream of a choke, in the form of a tube making it possible to absorb the majority of the necessary pressure drop, the choke itself making it possible to adjust the pressure in the range between 0 and 10 bar, that is to say on a range that does not cause significant degradation of the polymer. The combination of a pressure reducer, whose dimensions can be calculated on earth, with a choke whose role is to adjust the pressure without significantly degrading the polymer solves the problem described above. This makes it possible to limit the degradation of the polymer in a completely acceptable manner by reducing it to less than 10%. For example, on a well where the pressure reduction required is of the order of 50 bar, the pressure reducer provides a pressure drop of about 45 bar and the choke from 0 to 10 bar.
    [0013] The subject of the invention is therefore an apparatus for controlling the injection pressure of a polymeric aqueous solution in an underwater oil well, said apparatus being capable of being immersed and consisting of: a pressure reducer under the form of at least one tube intended to be inserted between two sections of main injection pipe, the pressure reducer having a diameter smaller than that of the main pipe and being able to absorb the majority of the pressure drop; - A choke positioned immediately upstream or downstream of the pressure reducer, said choke being adapted to be adjusted to allow a pressure control of between 0 and 10 bar. According to the invention, the pressure reducer is capable of absorbing at least 60% of the pressure drop, preferably at least 80%, more preferably at least 90%.
    [0014] In a preferred embodiment, the pressure reducer tube comprises at least one section of flexible tube, which makes it easier to handle the tube in a submarine environment during its installation or maintenance by divers or engineers. underwater robots.
    [0015] The pressure reducer comprises one or more sections of flexible tube connected end to end between them and the choke by quick couplings for easy attachment. The so-called fast connectors are well known to those skilled in the art because they allow easy connection of the elements to each other, including under difficult handling conditions such as the underwater environment. They are also called quick connection systems. The flexible tubes are selected from all types of flexible hoses made of plastic, rubber or composite. They are preferably made of a composite rubber-textile or metalloplastic capable of withstanding high pressures, at least equal to the pressure of the injection pump. In an alternative embodiment, the linear pressure reducer comprises one or more rigid metal tube sections connected in series with each other and with the choke 15 directly or through flexible tubes. In this case, the one or more rigid metal tube sections are in a spirally wound form. In practice, the metal tubes are made of stainless steels, in particular so-called "superduplex" or surface-hardened austenitic steels (vacuum nitriding, kolsterization) having a high mechanical strength as well as a high resistance to corrosion. corrosion. The pressure reducer is positioned downstream or upstream of the choke. The pressure control apparatus according to the invention is positioned downstream of the manifold (manifold). The inner diameter of the tube is between 1 inch (1.27 cm) and 4 inches (10.16 cm), preferably between 14 (1.27 cm) and 3 inches (7.62 cm). This diameter is small compared to the internal diameter of the main injection line, which is of the order of 10 inches (25.4 cm). In other words, the pressure reduction in a 10 inch (25.4 cm) inner diameter tube is considered insignificant within the scope of the invention, whereas the pressure reduction in a tube of diameter between 1/2 (1.27 cm) and 4 inches (10.16 cm) is significant without causing significant degradation of the polymer. Indeed, in the main lines of injection, the speed is of the order of 2 to 3 meters second while it reaches 6 to 14 meters / second in the tube of the linear pressure reducer.
    [0016] The length of tube constituting the pressure reducer is between 10 and 1000 meters, preferably between 50 and 600 meters. The subject of the invention is also a process for reducing the polymer injection pressure as a function of the well fracturing pressure using the apparatus previously described in a process for assisted oil recovery in the offshore. More precisely, the method according to the invention comprising the following steps: - Calculate the necessary pressure reduction by subtracting the injection pressure at the wellhead from the pressure of the main injection pump; - Determine, by means of tests on the ground, the dimensioning and the nature of the constituent tube of the pressure reducer, in such a way that the loss of load is equal to the reduction of necessary pressure minus that brought by the choke, and this, under the conditions injection of the polymeric aqueous solution on fields; - Immerse and connect the pressure reducer with the choke and insert the pressure control device thus obtained, between two submerged sections of injection pipe; Inject the aqueous polymeric solution into the main pipe. Sizing means the total length of the tube, the number of sections and the diameter of the tube section or sections. By nature is meant the tube section composition material (s). The pressure control apparatus according to the invention is preferably positioned downstream of the manifold (manifold) before the choke. During operation, the required pressure drop may vary. In the method according to the invention the pressure control can be carried out thanks to the opening or closing of the choke controlled at a distance from the platform or the boat FPSO. It can also be done by lengthening or reducing the length of the tube by adding or removing tubing section, through the intervention of divers or underwater robots. This manipulation is all the easier as the tube section or sections are flexible and quick couplings are used.
    [0017] More specifically, the pressure control provided by the choke is between 0 and 10 bar, preferably between 1 and 5 bar.
    [0018] Those skilled in the art can make adaptations of the apparatus and the process for each particular case. The invention and the advantages derived therefrom will emerge from the following examples, in support of the appended figures. FIG. 1 is a curve representing, for a given polymeric solution, the pressure drop as a function of the flow velocity, in tubes 107 meters long and of variable diameter (from one half to two inches, of 1, 27 to 5.08 cm). The polymer solution contains 1000 ppm of an acrylamide / sodium acrylate copolymer (70/30 mol%) having a molecular weight of approximately 20 million g / mol dissolved in a brine containing 5 WI of NaCl, 0.113 g / l of MgSO 4 and 0.096 g / l CaCl 2.
    [0019] FIG. 2 is a curve showing the pressure drop as a function of flow with the same polymer solution and the same tubes as in FIG. 1 FIG. 3 is a curve representing the degradation of the polymer in percent as a function of the flow rate , with the same polymer solution and the same tubes as in FIG. 1 and a pressure drop determined for this same polymer. The degradation of the polymer is directly proportional to the loss of viscosity of the polymeric solution. Figure 4 shows a schematic view of a floating production, storage and offloading (FPSO) unit and underwater injection architecture. Figure 5 shows a schematic view of the pressure control apparatus connected in series to the main line, downstream of the manifold. The apparatus consists of a linear pressure reducer of 3 sections of tube, and a choke, all connected by quick couplings.
    [0020] Installation Example Figure 4 shows a typical offshore secondary oil recovery facility. It includes a floating production, storage and offloading (FPSO) unit. The platform is equipped with riser tubes (2) into which the polymer solution is injected by means of the main injection pump. Each tube is intended to feed a manifold or distributor (3) from which leave as many tubes (4) as wells (5). The diameter of the tube feeding the manifold is the same as that of the tubes (4) leaving the manifold. In practice, the diameter is of the order of 10 inches (25.4 cm). In this installation of the prior art, the pressure decrease at each well (5) is obtained by placing a choke (6) on each pipe (4). As explained above, these chokes, by decreasing the pressure do not present a problem for water injections only but degrade the polymer when a polymeric aqueous solution is injected. To overcome this drawback and as shown in Figure 5, the invention consists in associating with each choke, a pressure reducer. The characteristics of the pressure reducer are calculated so that the cluse only intervenes at a level of 0 to 10 bars in the reduction of the injection pressure. The device of the invention is positioned downstream of the collector (3) on each of the tubes (4) from the main pipe (2). In Figure 5, the control device of the invention (10) consists of the pressure reducer (7) and the cluse (6). The pressure reducer (7) is itself constituted for example by 3 sections of tube (8) connected to each other as well as to the choke (6) and to the main pipe (4), by means of couplings fast (9). The inner diameter of the tubes (7) is smaller than that of the tubes (4), in practice less than 4 inches (10.16 cm). The jets (6) are connected, again by a quick coupling (9) to the downstream injection main line (4) and supplying the wells (5) in polymer solution. The internal diameter of the tube (4) between the choke (6) and the well (5) is identical to that of the other 30 portions of main pipe. Practical Example of Implementation On an offshore oil field, a 2000 ppm concentration polymer solution is produced from a 70/30 acrylamide / sodium acrylate copolymer emulsion of molecular weight 20 million and injected into a set wells via risers, manifolds and pressure regulating chucks. The viscosity is 200 centipoise.
    [0021] The pressure of the injection pump is 115 bars and we have chosen a line where the injection pressure at the wellhead is 77 bars. The choke and negligible load losses in line reduce the pressure by 38 bar.
    [0022] The flow measured on this well is about 91 m3 / 11 and the pressure / volume has been practically stabilized for more than a year. Ground tests are performed to select the size of the sections of the linear pressure reducer tube required by dissolving 2000 ppm of polymer in a brine of composition. NaCl 15.4 g / I NaHCO3 0.62 g / l CaC12.2H20 2.54 g / 1 MgCl2.61-120 2.54 g / 1 The tests are carried out on various flexible hoses and we chose a rubber tube type 4SP-32 with an inside diameter of 2 inches (5.08 cm). The working pressure to simulate the injection pressure is 165 bar, with a breaking pressure of 660 bars (Phoenix-Beattie brand). The velocity of the liquid in the tube is 12.5 meters per second and the pressure drop over 100 meters (test length) is 8.3 bars. This is quite acceptable compared to the objective since less than a pressure drop of 1 bar per 10 meters. 25 11a was chosen to install at the front of the choke a total tube length of 450 meter linear pressure reducer with three tube sections of length 50 meters and I 300 meter tube section, all assembled by quick couplings.
    [0023] When the polymer solution is injected, the initial pressure on the well drops to 77 bar, due to the effect of drag reduction of the polymer to go up to 79 bar. The flow rate is 93 m3ftteure with a completely open choke, but with a closing potential to increase the pressure drop in the choke by 10 bars with little degradation of the polymer. The choke is slightly closed to generate a pressure drop of 2 bar which makes it possible to reach the objective of 77 bars in injection pressure. If the required pressure drop varied slightly it would be easy to remotely control the opening or closing of the choke.
    [0024] If the pressure loss varied more significantly with respect to the pressure drop required, it would then be possible to remove or add one or two short sections of 50 meters each corresponding to a pressure loss of about 4. bars. The ground tests indicated a degradation over 100 meters of LPR of 1.2%, that is to say practically zero given the accuracy of the measurement. The purpose of the installation is therefore achieved.
    权利要求:
    Claims (7)
    [0001]
    CLAIMS1 / Injection pressure control device (10) of a polymeric aqueous solution in a subsea oil well, said apparatus being capable of being immersed and consisting of: a pressure reducer (7) in the form at least one tube (8) to be inserted between two sections of main injection pipe, the pressure reducer (7) having a diameter smaller than that of the main pipe (2) and being able to absorb the majority loss of charge; a choke (6) positioned immediately upstream or downstream of the pressure reducer (7), said choke (6) being adjustable to allow a pressure control of between 0 and 10 bar.
    [0002]
    2 / Apparatus (10) according to claim 1, characterized in that the tube (8) of the pressure reducer comprises at least one section of flexible tube.
    [0003]
    3 / Apparatus (10) according to claim 1, characterized in that the pressure reducer (7) comprises one or more flexible tube sections (8) connected end to end between them and the choke (6) by quick couplings allowing easy attachment.
    [0004]
    4 / Apparatus (10) according to one of claims 3 or 4, characterized in that the or flexible tubes (8) consist of a rubber-textile or metalloplastic composite capable of withstanding a pressure at least equal to the pressure of the injection pump.
    [0005]
    5 / Apparatus according to one of the preceding claims, characterized in that the pressure reducer (7) comprises one or more sections of tube (8) rigid metal connected end to end between them and the choke (6) directly or via flexible tubes (8).
    [0006]
    6 / Apparatus (10) according to claim 5, characterized in that the or the tubes (8) 30 metal are wound spirally.
    [0007]
    7 / Apparatus according to claim 1, characterized in that the diameter of the inner tube (7) is between V2 inches (1.27 cm) and 4 inches (10.16 cm). 8 / Apparatus according to claim 1, characterized in that the length of tube (8) is between 10 and 1000 meters.9 / Method for reducing the polymer injection pressure as a function of the pressure of the well implementing the apparatus (10) object of one of claims 1 to 8 in a method of assisted oil recovery offshore. 10 / A method according to claim 9, characterized in that it comprises the following steps: Calculate the necessary pressure reduction by subtracting from the pressure of the main injection pump, the injection pressure at the wellhead; Determine, by means of ground tests, the dimensioning and the nature of the tube constituting the pressure reducer (7) in such a way that the pressure drop is equal to the reduction in pressure required minus that provided by the choke, and this, in the injection conditions of the polymeric aqueous solution on fields; Immerse and connect the pressure reducer (7) with the choke and insert the pressure control device (10) thus obtained, between two submerged sections of the injection pipe; Injecting the aqueous polymeric solution into the main pipe (2), 11 / The method of claim 10, characterized in that the pressure control provided by the choke (6) is between 0 and 10 bar. 12 / A method according to claim 11, characterized in that an additional tube section is added or removed one by the intervention of divers or submarine robots, to modify the pressure drop provided by the pressure reducer ( 7) linear.25
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    法律状态:
    2015-10-30| PLFP| Fee payment|Year of fee payment: 2 |
    2016-04-08| PLSC| Publication of the preliminary search report|Effective date: 20160408 |
    2016-10-31| PLFP| Fee payment|Year of fee payment: 3 |
    2017-10-24| PLFP| Fee payment|Year of fee payment: 4 |
    2018-10-27| PLFP| Fee payment|Year of fee payment: 5 |
    2019-10-30| PLFP| Fee payment|Year of fee payment: 6 |
    2020-10-29| PLFP| Fee payment|Year of fee payment: 7 |
    2021-10-28| PLFP| Fee payment|Year of fee payment: 8 |
    优先权:
    申请号 | 申请日 | 专利标题
    FR1459378A|FR3026773B1|2014-10-01|2014-10-01|INJECTION PRESSURE CONTROL APPARATUS IN THE ASSISTED RECOVERY OF OFFSHORE OIL|
    FR1459378|2014-10-01|FR1459378A| FR3026773B1|2014-10-01|2014-10-01|INJECTION PRESSURE CONTROL APPARATUS IN THE ASSISTED RECOVERY OF OFFSHORE OIL|
    US14/520,945| US9328589B2|2014-10-01|2014-10-22|Apparatus for controlling injection pressure in offshore enhanced oil recovery|
    GB1418763.7A| GB2518065B|2014-10-01|2014-10-22|Apparatus for controlling injection pressure in offshore enhanced oil recovery|
    PCT/FR2015/052559| WO2016051051A1|2014-10-01|2015-09-25|Apparatus for controlling injection pressure in assisted offshore oil recovery|
    BR112017006384A| BR112017006384A2|2014-10-01|2015-09-25|apparatus for controlling the injection pressure of an aqueous polymer solution in an underwater oil well, and process for reducing the injection pressure of a solution.|
    MX2017004067A| MX2017004067A|2014-10-01|2015-09-25|Apparatus for controlling injection pressure in assisted offshore oil recovery.|
    CN201580052249.XA| CN107075933A|2014-10-01|2015-09-25|For controlling marine intensified oil reduction to inject the device of pressure|
    AU2015326712A| AU2015326712A1|2014-10-01|2015-09-25|Apparatus for controlling injection pressure in assisted offshore oil recovery|
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