EP2877675B1 - Système et procédé de production d'un fluide primaire, tel que du pétrole, à partir d'un réservoir souterrain - Google Patents

Système et procédé de production d'un fluide primaire, tel que du pétrole, à partir d'un réservoir souterrain Download PDF

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Publication number
EP2877675B1
EP2877675B1 EP13759834.8A EP13759834A EP2877675B1 EP 2877675 B1 EP2877675 B1 EP 2877675B1 EP 13759834 A EP13759834 A EP 13759834A EP 2877675 B1 EP2877675 B1 EP 2877675B1
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Prior art keywords
plug
pump
tubing
fluid
production
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EP13759834.8A
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German (de)
English (en)
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EP2877675A2 (fr
Inventor
Bert Fennechienes ALBERTS
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Karizan Bv
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Karizan BV
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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
    • E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
    • E21B23/14—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for displacing a cable or a cable-operated tool, e.g. for logging or perforating operations in deviated wells
    • 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
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • 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
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • E21B43/121—Lifting well fluids
    • E21B43/129—Adaptations of down-hole pump systems powered by fluid supplied from outside the borehole
    • 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
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • E21B43/121—Lifting well fluids
    • E21B43/122—Gas lift
    • E21B43/123—Gas lift valves
    • 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
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • E21B43/121—Lifting well fluids
    • E21B43/124—Adaptation of jet-pump systems

Definitions

  • the present invention relates to a system for production of a primary fluid, such as oil, from an underground reservoir, comprising:
  • a system according to the preamble of claim 1 is known in the art and is described in the Dutch patent application NL8602658 .
  • the known system relates to a pumping device for pumping a fluid, especially oil, out of a well to the ground surface.
  • the plug-in device comprises a pump and a hydraulic drive for the pump, wherein the drive is arranged at a position below the pump seen in the direction towards the underground reservoir.
  • the known system has many advantages.
  • the main advantage lies in the use of wire line techniques to pull the pump out of the tubing and change it or repair it and install it afterwards into the tubing, to overcome malfunctions.
  • the invention has for its object to further improve the known system.
  • each plug-in device provides a different technical function in relation to production of the primary fluid, wherein the secondary fluid lines are connectable to the plug-in device for operating the plug-in device
  • the system provides a set of plug-in devices that are each arranged to perform a specific function. All plug-in devices can be standardized with respect to the dimensions and can be interchanged quickly using the wire line techniques known in the art.
  • the most important function relates to the pumping function and necessitates a drive, preferably a hydraulic drive.
  • a drive preferably a hydraulic drive.
  • the position of the pump and the drive are reversed As seen in the longitudinal direction of the tubing the drive is positioned closer to the surface than the pump. This brings about the important possibility of using a pump with flexible dimensions.
  • the pump capacity largely depends on the dimensions of the pump, which can be adapted to the specific well conditions when using the system according to the invention.
  • the functional section of a second one of the plug-in devices comprises an internal passage for unobstructed flow of the primary fluid.
  • the plug-in device is arranged as a blind plug allowing testing of the proper functioning of the well.
  • this first preferred embodiment allows for water injection or steam injection, which are different techniques used in the field of oil production. Water injection wells can be found both on- and offshore to increase oil recovery from an existing reservoir. It is well known in the art to produce wells in a cyclic steam manner for a few cycles (also known as the huff and puff method) before being put on the steam-flooding regime with other wells.
  • an open cage is connected to the second one of the plug-in devices for accommodating measurement devices, such as temperature, pressure or flow measurement devices.
  • the plug-in device is arranged to function as an observation plug allowing determination of the prevailing well conditions.
  • the functional section of a third one of the plug-in devices is arranged for injection of a tertiary fluid into the reservoir through the secondary fluid lines, wherein the functional section comprises a number of flow out openings for the tertiary fluid.
  • the plug-in device allows for injection of gas for gas lifting of the oil out of the reservoir.
  • This third preferred embodiment can also be used to inject chemical solvents to clean the well equipment underground thereby increasing production.
  • the flow out openings are provided with closure means that are pretensioned in the closed position.
  • the pretension force can be chosen carefully to provide a back pressure and to make sure that there is no leakage of oil emulsion into the secondary fluid lines of the tubing.
  • the tertiary fluid is water or gas, wherein the drive is arranged to be driven by the tertiary fluid, wherein the tertiary fluid can be discharged by mixing it with the primary fluid produced by the system.
  • the drive is a hydraulic drive arranged to be driven by a hydraulic fluid to be fed through the secondary fluid lines.
  • the pump is a plunger or piston pump, a positive displacement pump or a centrifugal displacement pump.
  • a number of plug-in devices comprise at least two functional sections arranged adjacently, such that as seen in the longitudinal direction of the tubing the first functional section is positioned closer to the surface than a second functional section.
  • the second functional section comprises a pump for production of the primary fluid and the first functional section comprises a drive for the pump, wherein a jet pump or a gas lift valve is arranged in the second functional section between the drive and the pump.
  • the jet pump is a venturi jet pump.
  • the drive is a turbo motor drive.
  • the pump is a centrifugal pump.
  • the invention further relates to a method of which the steps are described in the independent method claim.
  • Figure 1A shows a schematic view of a part of a system 1 for production of a primary fluid according to the present invention.
  • Figure 1B shows system 1 in cross section.
  • System 1 is a Wire line Retrievable Oil Production (WROP) system.
  • System 1 comprises a casing 10 that is to be put into the ground wherein an underground reservoir of primary fluid is present.
  • Casing 10 normally has a tubular shape defining an internal elongate hollow tubing 11 that in the position of use runs in the direction of the reservoir (not shown).
  • Casing 10 comprises at least two lines 15 for secondary fluids that run in longitudinal direction substantially parallel to the tubing 11. Each line has an inlet/outlet 12, 13 that can be used both as an inlet and as an outlet.
  • Locking means lock the plug-in device 20 in place in tubing 11.
  • Suitable locking means are available in the relevant art and may comprise, for example, a landing nipple or a locking mandrel.
  • system 1 comprises a set of two or more plug-in devices each providing a different technical function in relation to production of the primary fluid.
  • plug-in devices each providing a different technical function in relation to production of the primary fluid.
  • FIGS 2 , 3 , 4 and 5 four different embodiments are shown. All of these embodiments are preferably at least in part standardized. In the preferred embodiments shown all plug-in devices comprise a part largely similar to the part shown in figure 2 .
  • a functional section 24 is present that is arranged according to the function to be fulfilled by the plug-in device.
  • a blind plug is shown.
  • an observation blind plug is shown.
  • a gas (or fluid) injection plug is shown and in figure 5 a plug with hydraulic drive and pump is shown.
  • Each of the plug-in devices can be selected, installed and operated for an optimal production of the primary fluid, as will be described in more detail in the following.
  • Plug-in device 20 is a so-called blind plug that can be used to test a production well.
  • Plug-in device 20 comprises a generally tubular body 21.
  • Plug-in device 20 is provided with locking means formed by a locking mandrel 22. Suitable locking mandrels are available in the art.
  • four seals 23 are present on the circumference of body 21.
  • the functional section 24 extends between adjacent seals.
  • body 21 comprises an internal passage for substantially unobstructed flow of the primary fluid.
  • the blind plug 20 is useful for checking operational pressures in the secondary fluid lines 15.
  • Plug-in device 20 is a blind plug closing off the inlet/outlet 12, 13 of the secondary fluid lines 15. Once the plug-in device 20 is locked in position by the locking means 22, the sealing means 23 and part of the body 21 seal off the inlet/outlet 12 and the inlet/outlet 13 of the secondary fluid lines 15 of the tubing 11 (see figure 1B ). Blind plug 20 is also very useful for water injection, which is commonly used in oil production to increase pressure and thereby stimulate production. The oil is literally swept or displaced in the reservoir.
  • Suitable materials and seals need than to be chosen that can withstand the higher temperatures.
  • FIG. 3 shows a cross section of a second embodiment of a plug-in device.
  • Plug-in device 30 according to figure 3 has the part 20 shown in figure 2 .
  • Plug-in device 30 is shown in the position of use wherein an open cage 31 is connected to the body 21 for accommodating measurement devices, such as temperature, pressure or flow measurement devices (not shown).
  • the cage construction 31 will protect the measurement devices during installation respectively retrievement of the plug-in device in respectively out of the tubing.
  • the blind plug 20 will protect the secondary fluid lines 15.
  • Plug-in device 30 is very suitable to observe the flow, temperature and pressure in the well.
  • FIG. 4 shows a cross section of a third embodiment of a plug-in device 40.
  • Plug-in device 40 is a so-called gas lift plug. In the field of oil production gas lift is commonly used when an oil well has insufficient reservoir pressure to produce oil. Injected gas aerates the fluid to reduce its density. The formation pressure is then to lift the oil column and force the fluid out of the well bore.
  • the plug-in device 40 is arranged for injection of a suitable gas or fluid, called tertiary gas or fluid, through the secondary fluid lines 15. Arrows G indicates the direction of gas flow, while arrows O indicate the direction of flow of oil (emulsion) from the well.
  • the sealing means 23 surround the inlets 12 and 13 of the secondary fluid lines 15 of the tubing 11 (see figure 1B ). Suitable openings (not shown) in plug-in device 40 allow for a gas flow G to enter the plug-in device 40 through the inlets.
  • the functional section 44 comprises a number of flow out openings 45 for the tertiary gas or fluid to mix with the oil emulsion.
  • flow out openings 45 are closed off with valves 46 that are pretensioned in the closed position by means of springs 47
  • plug-in device 40 can also be used to inject chemical solvents to remove unwanted deposit for example paraffin present in the tubing, lines and other underground production equipment.
  • the parts of plug-in device 40 that come into contact with the chemicals to be injected need to be carefully chosen, but suitable materials are available in the relevant art.
  • Plug-in device 50 is shown schematically (left) and in cross section (right).
  • Plug-in device 50 comprises a first functional section 54 that is arranged as a drive 55 for a pump 57 that is present in a second functional section 56 connected to the first functional section.
  • Plug-in device 50 is shown in the position of use. It is apparent that in the position of use the second functional section comprising the pump lies closer to the reservoir than the first functional section 54.
  • the sealing means 23 surround the inlet/outlet 12 and the inlet/outlet 13 of the secondary fluid lines 15 of the tubing 11 (see figure 1B ). Openings 24 in plug-in device 50 allow for a flow F of hydraulic fluid via the inlet 12 and the outlet 13 to cause rotation R of the drive 55.
  • Turbine motor 55-1 or positive displacement motor 55-2 are both available on the market and can be coupled to a suitable pump 57.
  • the drive 55 is arranged to allow for upward passage of the primary fluid that is pumped out of the reservoir.
  • a hollow central rod allows for passage of oil.
  • Suitable pumps are a plunger or piston pump, a positive displacement pump or a centrifugal displacement pump.
  • a piston pump is used in applications at lower pressure, for instance lower than 70 bars. In higher pressure applications ranging up to 2000 bar, plunger pumps are used. Both types of pumps use a cylindrical mechanism to create a reciprocating motion along an axis thereby building up pressure inside to force fluid through the pump.
  • the overall capacity of the piston pumps and plunger pumps can be calculated using the area of the piston or plunger, the stroke length, the number of pistons or plungers and the speed of the drive. The position of the pump below the hydraulic drive as seen in the direction of the oil reservoir allows the dimensions of the pump to be flexibly adapted to the circumstances of the well.
  • openings 24 are suitable for use in the plug-in device 40 to allow for a gas flow G to enter the plug-in device 40 via the inlets.
  • the method according to the invention comprises the following steps:
  • Figure 6 schematically shows a cross section through a typical well bore 100 in which a system according to the invention is present.
  • the configuration of the well bore may have several layouts with different lengths, depths, angles and dimensions.
  • the well bore configuration shown is just one of many possibilities and serves for illustrational purposes only.
  • P1 through P6 illustrate different positions for the plug-in devices 20, 120 in the tubing 11.
  • Figure 7A schematically shows a general view of part of a second embodiment of the system and figure 7B shows another part of the system of figure 7A in cross section.
  • Figure 7A shows a second embodiment of a plug-in device or WROP-tool 120.
  • Figure 7B shows part of the casing or WROP-nipple for receiving the WROP-tool.
  • Plug-in device 120 has a first functional section A extending between adjacent seal elements or areas 123 similar to the plug-in device 20. Additionally plug-in device 120 has a second functional section B arranged adjacent to the first functional section A.
  • the second embodiment of the system comprises a plug-in device 120 having two functional sections A and B that are arranged adjacently, such that as seen in the longitudinal direction of the tubing the first functional section A is positioned closer to the surface than the second functional section B.
  • the plug-in device 120 is based on the fourth embodiment 50 shown in figure 5 .
  • Table 1 lists a number of preferred embodiments of functional sections of plug-in devices, including the preferred embodiments discussed above.
  • the embodiments of the functional sections of the plug-in devices that are also referred to as WROP-tool elements are denoted by abbreviations of the name thereof.
  • the possible position P of the WROP-tools in the well bore configuration of figure 6 is listed as well as the position in the functional sections A, B in the second embodiment in figure 7A .
  • Table 2 lists a number of combinations of pairs of preferred embodiments of functional sections in table 1 in said positions A and B of plug-in devices.
  • the WROP-tools can be used in the oil & gas, water, geothermal, the general and nuclear industries.
  • the HLE-lines 15 can contain the following medium: Water (emulsion), Hydraulic Oil, Gas and Chemical solvents. Other liquids or gasses are possible.
  • the WROP - BLP is a Blind Plug functional section discussed referring to figure 2 .
  • the use of a blind plug is to close the HLE-1 or HLE-2 lines 15, to protect the sealing means in the WROP-Nipple to keep the HLE lines 15 under pressure whilst installing the completion with the HLE lines and/or to secure a good installation.
  • the BLP can be combined with all other WROP Down hole Tools (See Table 2).
  • the WROP - OBP is an Observation Blind Plug, i.e. an example of a functional section as in plug-in device 30 discussed referring to figure 3 .
  • the observation blind plug is provided with additional parts for assembling measurement devices onto the plug, such as temperature recording devices, flow meters and recording devices, pressure indicators and recording devices et cetera.
  • the OBP can be combined with all other WROP Down hole Tools (See Table 2).
  • the WROP - GLV is a Gas Lift Valve functional section similar as in plug-in device 40 discussed referring to figure 4 .
  • the WROP-GLV is a standard tool element, which can be installed in a standard tubing nipple. Gas is flowing though the HLE-Line(s) and pressured into the WROP-nipple and WROP-GLV tool element sections against a spring or gas loaded bellows. When the gas-pressure is strong enough to press the spring /bellows downwards or upwards (depends on the position of the GLV) the gas can float through small openings in the inside wall of the GLV tool element.
  • the spring/bellows is securing the well pressure and prevents ingress of emulsion into the HLE-lines by closing the openings when the gas pressure in the HLE-lines is not high enough. When the gas pressure is high enough the gas can get out of the tool element, but the well emulsion cannot get into the HLE Lines.
  • the GLV tool element can be combined with all other WROP Down hole tool elements (See Table 2).
  • the WROP - CIP is a Chemical Injection Valve, i.e. an example of a functional section as in plug-in device 40 discussed referring to figure 4 .
  • the tool-lay-out is almost equal to the GLV, but the main difference is that instead of gas, a chemical solvent or fluid can be pressed into the wellbore solving paraffin particles.
  • Preferred place of the CIV is below a WROP-GLV or WROP- VJP to solve the hard particles before they enter the Gas-Lift section or the Jet-Pump section.
  • the GLV tool element can be combined with all other WROP Down hole tool elements (see Table 2).
  • the WROP - VJP is a Venturi Jet Pump i.e. an example of a functional section 56 of a plug-in device 50 discussed referring to figure 5 .
  • the WROP-Venturi Jet Pumps can be adapted to run in a wide variety of bottom hole cavities and down hole tools.
  • the actual working components of the jet pump are a nozzle, throat and diffuser. These components can be wire line retrievably assembled in a variety of configurations and materials to suit the production requirements and down hole environment by a person skilled in the art.
  • a drive medium or power fluid at high pressure (low velocity) transported from surface down hole by the HLE-Line(s) and to the VJP is converted to a low-pressure (high velocity) jet by the nozzle.
  • the pressure at the entrance of the throat becomes lower as the power fluid rate is increased.
  • This pressure becomes lower than the pressure in the suction passageway, primary fluid is drawn in from the wellbore.
  • the primary fluid or suction fluid becomes entrained with the high velocity jet and the pumping action then begins.
  • the combined power fluid and suction fluid is slowed down by the diffuser. Because the velocity is reduced, the pressure increases rising to a value sufficient to pump the combined fluid to the surface.
  • a full range of nozzle and throat sizes should be available to allow power fluid rate and pressure to be varied to meet various flow rates.
  • a WROP-GLV Gas Lift Valve
  • Option A the upper functional section
  • This will be beneficial for the surface installed pump-unit and can decrease the power input into the HLE-Line(s).
  • WROP - SAV is a Safety Valve functional section for a plug-in device.
  • the Wire-line Retrievable Ball or flapper valve which is normally closed, is held open by hydraulic control pressure trough the HLE-Line from the surface.
  • the valve operates on a hydraulic piston principle. To open, hydraulic pressure slightly higher than the well pressure is applied to move the piston downward. This pressure unseats a secondary seat, allowing pressure to enter through an equalizing port. Then as additional hydraulic pressure is applied to the piston, it continues downward movement, pushing the flapper open.
  • the WROP - PPP is a Piston Plunger Pump i.e. an example of a functional section 56 of a plug-in device 50 discussed referring to figure 5 .
  • the WROP - CEP is a Centrifugal Displacement Pump i.e. an example of a functional section 56 of a plug-in device 50 discussed referring to figure 5 . All combinations can be made in the quantity, type and dimensions of the centrifugal elements.
  • the driving Motor components See Table 3 WROP-TMD or WROP-DMD) can be different in speed, torque rates and feeder consumption (e.g. hydraulic oil).
  • the WROP - CAP is a Cavity Displacement Pump, i.e. an example of a functional section 56 of a plug-in device 50 discussed referring to figure 5 .
  • the cavity pump consists of a helical rotor and a twin helix, twice the wavelength and double the diameter helical hole in a rubber or metal-to-metal stator.
  • the rotor seals tightly against the stator as it rotates, forming a set of fixed-size cavities in between.
  • the cavities move when the rotor is rotated but their shape or volume does not change.
  • the pumped material is moved inside the cavities.
  • the driving Motor components See WROP-TMD or WROP-DMD
  • WROP-DMD WROP-DMD
  • feeder consumption e.g. hydraulic oil
  • WROP - HEX is a Heat Exchanger Plug-in device.
  • the HEX plug-in device can be used when aerial heat is required or can be attracted. The plug keeps the fluid content for a longer while in a heated zone or attracts the heat during a longer period. Combinations with almost all other WROP-tool elements are possible. Products can be used in General oil wells, Shale Oil (heating up the shale layer) and-Geothermal (extracting heat from down hole) Environments in a closed system without attracting or injecting water.
  • WROP - PAP is a Packer (de-) Activated Plug.
  • a packer can be installed by keeping pressure on the HLE-Line(s) and de-activating the packer seals. By releasing the pressure the seals are activated and installed, closing off a part of the space between tubing and casing (annulus).
  • the WROP - Check Valve is a spring/bellow loaded ball or flapper type check-valve (non return valve) can basically be assembled optionally under every WROP-configuration. The pre-tension of the spring/bellows can be adjusted to customer requirements.
  • the Motor Drive for WROP- CEP and WROP-CAP displacement pumps is an example of a functional section 54 of a plug-in device 50 discussed referring to figure 5 .
  • the WROP-TMD Turbo Motor Drive is an example of a functional section 54 of a plug-in device 50 discussed referring to figure 5 .
  • the TMD consists of a set of fixed turning vanes at the top of the motor (the stator vanes) which direct the flow of power fluid or drive medium going down the hole to flow onto a second set of vanes (the rotor vanes) which are pushed around by the flow, causing the drive shaft to which they are connected to rotate.
  • the WROP-DMD Displacement Motor Drive is an example of a functional section 54 of a plug-in device 50 discussed referring to figure 5 based on the principle developed by, Rene Moineau.
  • the theory states that a helical rotor with one or more lobs will rotate eccentrically when within a stator containing one or more lobs than the rotor.
  • the flow of this power fluid or drive medium transmits power allowing the assembly to rotate and turn the transmission-axle.
  • the length (stages), dimensions and shapes of the Stator and Rotor will determine the speed and torque rates, needed to drive the WROP-CEP and WROP-CAP pumps.
  • By using a hollow axle the primary fluid produced with the CEP or CAP can freely flow upwards.
  • the Hydra Fluid stream is a closed system.
  • Hydraulic fluids can be used to feed the HLE-Lines and thus the down hole WROP-Motors, but it is also possible to use the tertiary fluid like gas, water et cetera as propulsion means or drive media to drive the WROP-Motors.
  • the tertiary fluid can be discharged by mixing it with the primary fluid produced by the system.
  • propulsion means When these propulsion means go in the down hole motors they will perform the required movements in the motors. At the end of each motor the propulsion means can be used as injection purpose in a build-in Gas-Lift-Valve, Venturi Jet Pump, whilst the motor rotating movement can be guided downwards and activate to the Centrifugal or Cavity displacement down hole pumps.
  • HLE-1 and HLE-2 Hydra-Lines
  • HLE-2 Hydra-Lines
  • the extra lifting or pumping aids will lift the hydrostatic column, so the centrifugal/cavity pumps will be able to produce the reservoir (oil/water/gas) emulsion, i.e. the primary fluid, at an easier way. This will create an enormous benefit to the driving speed and/or torque rates of the centrifugal/cavity displacement pumps.
  • Table 3 lists a number of preferred embodiments of functional sections of plug-in devices, including the preferred embodiments discussed above.
  • the embodiments of the functional sections of the plug-in devices that are also referred to as WROP-tool elements are denoted by abbreviations of the name thereof.
  • FIG. 7C shows part of the second embodiment of figure 7A in more detail.
  • the second functional section B comprises a pump for production of the primary fluid and the first functional section A comprises a drive for the pump, wherein a jet pump or a gas lift valve is arranged in the second functional section B between the drive and the pump.
  • GTD Gas Turbo Drive
  • GLV Gas Lift Valve
  • B1 a Water Turbo Drive (WTD) is powered by water W.
  • B2 a Venturi Jet Pump is arranged and at B3 a Centrifugal Displacement Pump (CEP) or a Cavity Displacement Pump (CAP) is arranged.
  • B4 a Check Valve is present.
  • the Water Turbo Drive of B1 is shown in more detail comprising a stack of rotors R and Stators S.
  • the Venturi Jet Pump of B2 is shown in more detail comprising a diffuser D, a nozzle N and a throat T. F indicates the production flow comprising the primary fluid.
  • the system according to the invention has many advantages. In random order improvements of the pump ratio can be reached, shorter CAP / CEP pump can be chosen reducing costs and pump effects can be balanced even better than before. Furthermore profits will rise due to more production out of the reservoir and gas / water / emulsion can be reused for injection into the HLE-Lines.
  • All WROP-tool configurations are suitable in horizontal and vertical (highly deviated) situations and can be used onshore as well as offshore.
  • a plug-in device comprising a combination of a drive and a pump
  • the drive when installed at one of the positions P1 through P6, the drive is positioned closer to the surface than the pump, as seen in the longitudinal direction of the tubing.
  • a casing to be put into the ground for defining an internal elongate hollow tubing running in the direction of the reservoir is not an essential part of the system according to the present invention.
  • a suitable casing may already be present in the well bore and the system may be arranged to cooperate there with.
  • the secondary fluid lines running in longitudinal direction substantially parallel to the tubing may then form part of the system.
  • the tubing may be formed of WROP-nipples and pipe parts that are coupled, preferably in a releasable manner, to form the tubing. Suitable pipe parts and coupling means are available in the art.
  • the first plug-in device with a drive for a pump may be left out of the set.
  • wire line In the relevant technical field by wire line a cabling technology is meant used by operators of oil and gas wells to lower equipment into the well.
  • a flexible cable is used to let the plug-in devices sink into the tubing and/or to pull it up out of the tubing.
  • Several types of flexible cables known in the art are suitable in the context of the present invention, including wire line, such as described in NL8602658 , coiled tubing or flexible rod.

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Jet Pumps And Other Pumps (AREA)
  • Earth Drilling (AREA)

Claims (12)

  1. Système (1) de production d'un fluide primaire, tel que du pétrole, à partir d'un réservoir souterrain, comprenant :
    une enveloppe de puits (10) à mettre en place dans le sol pour définir une tubulure creuse interne allongée (11) s'étendant dans la direction du réservoir ;
    au moins un dispositif enfichable (20 ; 30 ; 40 ; 50 ; 120) destiné à être reçu dans la tubulure, lequel dispositif enfichable est muni de moyens (23) pour rendre étanche le dispositif enfichable dans la tubulure ;
    des moyens pour l'installation et l'enlèvement par câble du dispositif enfichable dans la tubulure ; des moyens (22) pour verrouiller et déverrouiller le dispositif enfichable dans la tubulure ;
    l'enveloppe de puits comprenant au moins deux lignes de fluide secondaires (15) s'étendant dans une direction longitudinale sensiblement parallèle à la tubulure,
    le système comprenant un ensemble de deux ou plusieurs dispositifs enfichables, chacun comprenant au moins une section fonctionnelle (24 ; 44 ; 54) s'étendant entre des moyens d'étanchéité (23) adjacents, la première section fonctionnelle (54) d'un premier dispositif enfichable comprenant un entraînement (55) pour une pompe (57), la pompe pouvant être connectée à l'entraînement de sorte que la pompe se trouve plus près du réservoir que la première section fonctionnelle, caractérisé en ce que
    chaque dispositif enfichable remplit une fonction technique différente en relation avec la production du fluide primaire, les lignes de fluide secondaires pouvant être connectées au dispositif enfichable pour faire fonctionner le dispositif enfichable.
  2. Système de production d'un fluide primaire selon la revendication 1, dans lequel la section fonctionnelle (24) d'un deuxième dispositif enfichable (20) comprend un passage interne pour un écoulement sans obstruction du fluide primaire.
  3. Système de production d'un fluide primaire selon la revendication 2, dans lequel une cage ouverte (31) est reliée au deuxième dispositif enfichable (30) pour recevoir des dispositifs de mesure, tels que des dispositifs de mesure de température, de pression ou de débit.
  4. Système de production d'un fluide primaire selon la revendication 1, 2 ou 3, dans lequel la section fonctionnelle d'un troisième dispositif enfichable (40) est conçue pour l'injection d'un fluide tertiaire dans le réservoir à travers les lignes de fluide secondaire (15), la section fonctionnelle (44) comprenant un certain nombre d'ouvertures d'écoulement (45) pour le fluide tertiaire.
  5. Système de production d'un fluide primaire selon la revendication 4, dans lequel les ouvertures d'écoulement (45) sont munies de moyens de fermeture (46) qui sont précontraints en position fermée.
  6. Système de production d'un fluide primaire selon la revendication 4 ou 5, dans lequel le fluide tertiaire est de l'eau ou du gaz, l'entraînement (55) étant conçu pour être entraîné par le fluide tertiaire, le fluide tertiaire pouvant être évacué en le mélangeant avec le fluide primaire produit par le système.
  7. Système de production d'un fluide primaire selon l'une ou plusieurs des revendications précédentes, dans lequel l'entraînement (55) est un entraînement hydraulique conçu pour être entraîné par un fluide hydraulique devant être amené par les conduites de fluide secondaire (15).
  8. Système de production d'un fluide primaire selon l'une ou plusieurs des revendications précédentes, dans lequel la pompe (57) est une pompe à piston plongeur ou une pompe à piston, une pompe volumétrique ou une pompe volumétrique centrifuge.
  9. Système de production d'un fluide primaire selon l'une ou plusieurs des revendications précédentes, dans lequel un certain nombre de dispositifs enfichables (120) comprennent au moins deux sections fonctionnelles (A, B) disposées de manière adjacente, de sorte que, vue en direction longitudinale de la tubulure, la première section fonctionnelle (A) est positionnée plus près de la surface qu'une deuxième section fonctionnelle (B).
  10. Système selon la revendication 9, dans lequel la deuxième section fonctionnelle (B) comprend une pompe pour la production du fluide primaire et la première section fonctionnelle (A) comprend un entraînement pour la pompe, une pompe à jet ou une valve à gaz d'ascension étant disposée dans la deuxième section fonctionnelle entre l'entraînement et la pompe.
  11. Système selon la revendication 10, dans lequel la pompe à jet est une pompe à jet venturi, un moteur d'entraînement turbo ou une pompe centrifuge.
  12. Procédé de production d'un fluide primaire, tel que du pétrole, à partir d'un réservoir souterrain, utilisant un système (1) selon l'une ou plusieurs des revendications précédentes 1-11, comprenant les étapes consistant à :
    a) sélectionner l'un des dispositifs enfichables (20 ; 30 ; 40 ; 50 ; 120) destinés à être reçus dans la tubulure ;
    b) installer le dispositif enfichable dans la tubulure en utilisant les moyens d'installation par câble ;
    c) verrouiller le dispositif enfichable dans la tubulure ;
    d) faire passer et installer la tubulure et les lignes secondaires à l'intérieur de l'enveloppe de puits dans le puits de forage ;
    e) actionner le dispositif enfichable en alimentant le dispositif enfichable en fluide secondaire ou tertiaire ;
    f) déverrouiller le dispositif enfichable de la tubulure ;
    g) enlever le dispositif enfichable de la tubulure à l'aide des moyens d'enlèvement par câble ; et
    h) éventuellement, répéter les étapes a, b, c, e, f et g pour le même dispositif enfichable, ou un autre dispositif enfichable.
EP13759834.8A 2012-07-10 2013-07-10 Système et procédé de production d'un fluide primaire, tel que du pétrole, à partir d'un réservoir souterrain Active EP2877675B1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
NL2009165A NL2009165C2 (en) 2012-07-10 2012-07-10 System and method for production of a primary fluid, such as oil, from an underground reservoir.
PCT/NL2013/050523 WO2014011043A2 (fr) 2012-07-10 2013-07-10 Système et procédé de production d'un fluide primaire, tel que du pétrole, à partir d'un réservoir souterrain

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EP2877675A2 EP2877675A2 (fr) 2015-06-03
EP2877675B1 true EP2877675B1 (fr) 2021-09-08

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US (1) US20150191984A1 (fr)
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WO (1) WO2014011043A2 (fr)

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NL2013043B1 (en) 2014-06-20 2016-07-06 Halpa Intellectual Properties B V System of flexible pipes and coupling elements and method of producing such a flexible pipe.
US20170074089A1 (en) * 2015-09-10 2017-03-16 Weatherford Technology Holdings, Llc Sensing cavitation-related events in artificial lift systems
NL2016185B1 (en) 2016-01-29 2017-08-10 Halpa Intellectual Properties B V Method for counteracting land subsidence in the vicinity of an underground reservoir.
CN110630198B (zh) * 2019-09-16 2020-05-05 中国石油天然气股份有限公司西南油气田分公司工程技术研究院 一种隔离式气举封隔器
US20230383620A1 (en) * 2020-11-06 2023-11-30 Weatherford Technology Holdings, Llc Float valve producing turbulent flow for wet shoe track

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GB778489A (en) * 1956-02-09 1957-07-10 Samuel Joseph Elsby Marshall Deep well pumping apparatus
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US4625798A (en) * 1983-02-28 1986-12-02 Otis Engineering Corporation Submersible pump installation, methods and safety system
NL8602658A (nl) * 1986-07-23 1988-02-16 Midco Nederland B V Pompinrichting en een pompeenheid daarvoor.
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US8069914B2 (en) * 2007-10-05 2011-12-06 Canasonics Inc. Hydraulic actuated pump system
US20100143166A1 (en) * 2008-09-12 2010-06-10 Philip Head Downhole pumping system

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Publication number Publication date
EP2877675A2 (fr) 2015-06-03
CA2891195A1 (fr) 2014-01-16
US20150191984A1 (en) 2015-07-09
CA2891195C (fr) 2021-06-22
WO2014011043A2 (fr) 2014-01-16
NL2009165C2 (en) 2014-01-13
WO2014011043A3 (fr) 2015-01-22

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