WO2020225432A1 - Dispositif de régulation de débit souple - Google Patents

Dispositif de régulation de débit souple Download PDF

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Publication number
WO2020225432A1
WO2020225432A1 PCT/EP2020/062911 EP2020062911W WO2020225432A1 WO 2020225432 A1 WO2020225432 A1 WO 2020225432A1 EP 2020062911 W EP2020062911 W EP 2020062911W WO 2020225432 A1 WO2020225432 A1 WO 2020225432A1
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WO
WIPO (PCT)
Prior art keywords
control device
flow control
flow
well
tubular
Prior art date
Application number
PCT/EP2020/062911
Other languages
English (en)
Inventor
Kristian Brekke
Original Assignee
Flowpro Control As
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Flowpro Control As filed Critical Flowpro Control As
Publication of WO2020225432A1 publication Critical patent/WO2020225432A1/fr

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Classifications

    • 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
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in 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
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/066—Valve arrangements for boreholes or wells in wells electrically actuated
    • 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
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/16—Control means therefor being 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
    • E21B43/02—Subsoil filtering
    • E21B43/08—Screens or liners
    • 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
    • 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
    • E21B43/14—Obtaining from a multiple-zone well
    • 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
    • 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
    • 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
    • E21B43/32—Preventing gas- or water-coning phenomena, i.e. the formation of a conical column of gas or water around wells

Definitions

  • the invention relates to system for a flow control device for use in a production pipe for producing oil and gas from, or for injecting fluids into a well in an oil or gas reservoir.
  • the invention particularly relates to a flow control device that configured to be adjusted prior to installing into the well.
  • the flow control device is simple, easily adjustable and time-efficient to adopt the different
  • the flow control device according to the invention is beneficial in that it reduces the cost in implementation of the flow control device in the field.
  • a further advantage of the flow control device according to the invention is to provide last minute adjustment of flow control device before installation. This will facilitate flow optimization based on actual well data. An increase of 10 % or more in oil production from the use of downhole flow control have been common for several fields.
  • Adjustments can adapt the completion to unexpected zone length/segments or formation quality.
  • the housing comprises a plurality of openings disposed around the periphery of the housing, each opening being in operational connection with separately arranged actuator arrangements.
  • each actuator arrangement comprises an actuator and a piston arrangement.
  • the flow control device comprises two set of ports, a first set of ports being fluidly connected between the outlet of the flow control device and the interior of the tubular line, a second set of ports being fluidly connected between the inlet of the flow control device and the interior of the tubular line, each of the ports having separately arranged actuator arrangements for moving the ports between a closed and open position.
  • the actuator arrangements are independently operable of each other.
  • the invention also concerns the use of a flow control device according to any one of the claims 1 -9, as a flow regulating device for production fluid and/or well treatment fluid in an oil and gas well.
  • Figure 1 shows a principle drawing of a horizontal well with a tubular line having a flow control device according to the invention.
  • Figure 2 shows a detailed view of a section of the tubular line comprising a flow control device according to an embodiment of the invention.
  • Figure 3-4 shows a perspective view of the flow control device according to an embodiment of the invention.
  • Figure 5 shows a detailed view of the flow control device from figure 3-4.
  • Figure 6 shows a detailed view of a flow control device according to a second embodiment of the invention.
  • FIG. 7a and 7b illustrating examples of check valves that can be used in the various embodiments of the flow control device according to the invention.
  • Figure 8 shows a schematic view of a lay out and flow diagram for an
  • Figure 9 shows a schematic comparison of the oil production with respectively a screen, a prior art flow control device and a flow control device according to the invention.
  • Figure 10 illustrating the simulated improved annulus acid coverage by a flow control device according to the invention compared to a regular inflow control device.
  • Figure 1 1 illustrating the simulated improved scale squeeze inhibition by a flow control device according to the invention compared to a regular inflow control device.
  • production mode it is meant the recovery of fluids from a subterranean formation, ie when the fluid, mostly oil, gas or water flows from the surrounding geological formations of the well into the production line and further out of the well.
  • “well treatment mode” or“injection mode” it is meant a circulation or squeeze operation where chemical, acid or other treatment fluid flows in the injection direction through the production line to the formation to perform work on the formation in order to increase the production rate from the well.
  • The“production mode” is stopped when performing the“well treatment mode” and vice versa.
  • annulus it is meant the space between the geological formation and the tubular line in the well.
  • annulus space is meant the space between the housing of the control device and the second base pipe with the openings for fluid.
  • production fluid any fluid that is present in the reservoir or formation that is allowed to flow into the tubular line.
  • the fluids are mostly oil, gas or water.
  • the production fluid follows a“production path” from the reservoir/geological formation into the tubular line 1.
  • treatment fluid chemicals, acid or other scale treatment fluid used in a maintenance operation to increase the productivity of the well, for instance by removing mud cake etc. that may build up in the annulus between the screen and the formation.
  • the treatment fluid follows an“injection path” from the tubular line to the formation or screen.
  • flow characteristic is meant the amount of fluid flowing out from or into the tubular line at each flow control devices and also the direction of the fluid flow.
  • Figure 1 illustrates an overview of a well 10 that is drilled horizontally through a geological formation 11.
  • the tubular line 1 comprises a plurality of screen joints 4 and flow control devices 3 connected to the base pipe 2.
  • a part of the base pipe 2 that is not enclosed by a screen joint 4 and a flow device 3 is hereinafter referred to a first base pipe part 2a for simplicity.
  • This base pipe part 2a does however not form a separate part of the base pipe 2. It is also the part of the pipe that is exposed to the surrounding well formation.
  • a further second base pipe part 2b is covered by the flow control device 3 and the screen joint 4.
  • the first and second base pipe part 2a, 2b of the base pipe 2 are not physically divided but forms a continuous base pipe 2 in each of the tubular segments 5 of the tubular line 1.
  • the base pipes 2 are screwed together in approximately 12 m lengths along the well 10.
  • Each of these tubular segments 5 have a screen 4 and a flow control device 3 to bring the fluid between the interior 30 (figure 4, 6) of the base pipe 2 and the screen 4.
  • the length of each segments 5, ie of each the base pipe 2 with screen 4 and control flow device 3 is only an illustrating example, other lengths are possible embodiments.
  • the tubular line 1 in the well 10 may comprise a plurality of such tubular segments 5 in a repetitive combination as shown in figure 1.
  • the figure 1 shows 4 tubular segments 5 forming the tubular line 1.
  • the tubular line 1 comprises between 100-200 tubular segments 5.
  • the figure 1 further discloses connections 21 to connect two base pipes 2 together. This is illustrated by a male/female coupling part 21 b, 21 a in figure 2. These coupling parts are arranged at each free end of the base pipe 2 in each tubular segment 5.
  • annulus packers 6 in the well.
  • the packers 6 forms seals in an annulus 12 between the base pipe 2 and the surrounding formations 1 1.
  • the packers 6 preferably surrounding the first base pipe part 2a.
  • the packers 6 may be arranged in a number of possible ways for instance can there be several tubular segments 5 between each packer 6. There can for instance be a packer 6 between every 10 th tubular segment or joints 5.
  • Figure 2 shows a single tubular segment 5 from figure 1 in more detail.
  • the tubular segment 5 comprising the first and second base pipe part 2a, 2b, the screen joint or section 4 and a flow control device 3, 50 according to the present invention assembled together as described above.
  • the flow control device 3, 50 is arranged at the end of the screen joint 4.
  • the first base pipe part 2a defines the distance between each assembled flow control devices 3, 50 and the screen joint 4.
  • the flow control device could also be a simple flow control device having only one opening connected to an actuator arrangement and thus possibility for only one flow path direction; injection or production.
  • the treatment fluid passes from an interior 30 (fig 3-7b) of the base pipe 2, through the flow control device 3, 50 to an annular space 13 between the screen joint 4 and the base pipe 2.
  • the treatment fluid further flows through the screen joint 4, into the annulus 12 and finally into the formation 11.
  • this flow path is reversed and the fluid from the formations, mostly oil, gas or water, flows from the formation into the annulus 12 and further through the screen joint 4, the annular space 13, through the flow control device 3, 50 to the interior 30 or the base pipe 2.
  • the fluid from the formations mostly oil, gas or water
  • the screen joint 4 is formed as a filter, for instance a sand filter.
  • the filter prevents grain or other particles from the formation to flow through the screen joint 4 and into the system 6.
  • the flow control device 3, 50 has at least one check valve 16a, 16b for inlet or outlet of fluid to or from the screen joint 4.
  • the flow control device 3, 50 has further a plurality of ports 15a, 15b or at least one opening 57a, 57b.
  • the ports 15a, 15b or at least one opening 57 allows the fluid flowing from the outside of the flow control device 3, 50 to the inside of the flow control device 3, 50.
  • FIG 3 and 4 shows a perspective view of a first embodiment of the flow control device 50 according to the invention.
  • This is a flow control device 50 with a plurality of openings 57 disposed around the periphery of the flow control device 50.
  • the flow control device 50 may be installed both in a production mode or an injection mode depending on the position in the well and the surrounding well formations.
  • the flexible flow control device 50 shown in the figures comprises a housing 51 (fig.4) with a plurality of openings 57 as illustrated in figure 3. In figure 4, each of the openings are covered by an erosion protective chamber 60.
  • the actuator arrangement 53 comprises an actuator 55, for instance a linear actuator as disclosed in the figures, and a piston arrangement 54.
  • the actuator 55 is operationally connected to the piston arrangement 54.
  • the actuator 55 is mechanically connected to the piston arrangement 54 to position the piston arrangement 54 in the intended position for the flow control device.
  • the piston arrangement 54 comprises a cylinder 58 and a piston 59.
  • the piston 59 is arranged within the cylinder 58 and is adapted to be moved longitudinally within the cylinder 58.
  • the cylinder 58 further comprising a number of orifices 52a, 52b, 52c allowing fluid to flow between the inside of the cylinder to the erosion protective chamber 60 in the space between the opening 57 and the cylinder 58.
  • Other arrangement for the flow from the cylinder 58 to the interior 30 of the flow control device 50 are also possible.
  • the piston 59 and orifices 52a, 52b, 52c are arranged so that the piston 59 covers or exposed the orifices 52a, 52b, 52c when moved within the cylinder 58. The piston 59 is therefore able to adjust the number of orifices 52a, 52b, 52c that are covered or exposed in the piston arrangement 54.
  • the actuator 55 is further communicating with a control device 61 , such as electronic device.
  • the control device further communicates wirelessly with a control panel (not shown) to adjust the position of the piston arrangement 54.
  • the control panel is operated remotely by an operator send signal to the control device in the flow control device.
  • the signal defines how many of the orifices 52a, 52b, 52c that are exposed and allow fluid to flow through.
  • the control device may be powered by a regular battery pack. It also does not require any configuration to be used in a well as all the adjustment is performed prior to the installation in the well.
  • the orifices 52a, 52b, 52c may have different diameter to vary the flow rate out of or into the flow control device.
  • the orifices 52a, 52b, 52c can be 2.5 mm, 5 mm and 10 mm.
  • the orifices 52a, 52b, 52c could however have equal diameter. Other diameters that in the example can also be possible embodiments of the invention.
  • the number of orifices in communication with one opening 57 could also be different than three.
  • the flow control device 50 further has a check valve 16b fluidly coupled to each of the openings 57 to allow fluid to flow from the reservoir and screen joint through the flow control device 50 to the interior 30 of the tubular line 1 .
  • the flow control device 50 may also have a check valve 16a that are oriented the opposite way allowing fluid flow from the interior 30 of the tubular line 1 through the flow control device 50 to the screen joint 4 and reservoir.
  • the check valve 16a, 16b could be a check valve having a fixed flow direction.
  • the check valve 16a, 16b can however be a reversable check valve that may be set as an inflow check valve or outflow check valve, depending on the requirement of the actual flow control device 50.
  • the check valve can for instance a check valve as illustrated in figure 7a, 7b. The invention is however not limited to these alternatives.
  • This adjustment of the flow control device 50 will further adapt the flow control device 30 to the actual reservoir and well conditions and stimulation
  • the simplest embodiment of the invention is a flow control device with only one opening 57 and one actuator arrangement 53 as indicated above. This flow control device further has only one valve in fluid connection with the opening 57. This embodiment is not shown in the figures.
  • a further embodiment of the invention has a number of openings 57 with associated actuator arrangements 53 and check valves 16a, 16b with the possibility of flow paths through the flow control device 50.
  • Figure 5 shows a schematic view of several openings 57 fluidly connected to the actuator arrangement 53 and check valve 16a, 16b.
  • the three uppermost arrangement shows the check valve 16a intended for flow from the flow control device 50 to the screen joint 4, while the three lowermost arrangements show the check valve 16b intended for flow from the screen joint 4 to the flow control device 50.
  • the figure further illustrates how the piston 59 can move within the cylinder 58 and close the orifices 52a, 52b. The fluid flows to/from the opening 57 through the orifice(s) 52a, 52b that are not closed by the piston 59 and further to from the check valve 16a, 16b.
  • FIG. 6 shows a simplified cross section of the flow control device 3 according to a second embodiment of the invention. There is shown a housing 19 having a first inlet 16a for injection of treatment fluid from the base pipe 2. The figure 6 shows a check valve 16a for the flow.
  • the check valve 16a can be any of the type shown in figure 4 referred to as 16a’ and 16a”.
  • the flow control device 3 in figure 6 shows further a second inlet 16b arranged in the housing 19 for the flow of production flow from the reservoir or formation 1 1 to the base pipe 2.
  • a plurality of inlet and outlet ports 15a, 15b are shown.
  • the production fluid flows from an inlet or check valve16b through an annular space 14b between the base pipe 2 and the flow control device 3, 50 and further the open ports 15b or exposed openings 52.
  • the well treatment fluid flows on the other hand from the interior 30 of the tubular line 1 through the open ports 15a or exposed openings to the annular space 14a and further out through the outlet or check valve 16a.
  • both injection and production paths are disclosed respectively with only two ports 15a, 15b.
  • one port 15a is in the open position and the other port 15a is closed.
  • a flow path for the injection path is illustrated by the arrows I.
  • both ports 15b, 15b are open.
  • a stream line for the production is illustrated by the arrows P.
  • the invention is however not limited to the two ports 15a, 15b arranged at each flow path of the injection control device 3. There may be arranged more than two ports in connection with each inlet or outlet check valvel 6a, 16b of the flow control device 3.
  • ports 15a, 15b shown in figure 2 are six ports 15a, 15b shown in figure 2 and eight ports 15a, 15b shown in figure 8.
  • Other number of ports 15a, 15b may however also be possible embodiments of the invention.
  • One single port 15a, 15b in the inlet control device 3 is further illustrated by a threaded plug 17a, 17b and an opening or orifice 18a, 18b.
  • the threaded plug 17a, 17b is able to move between an open position and a closed position. In the open position the threaded plug 17a, 17b is moved away from the orifice 18a, 18b. In the closed position, the threaded plug 17a, 17b is closing over the orifice 18a, 18b to prevent fluid flowing through the port 15a, 15b.
  • the threaded plug 17a, 17b is arranged to be opened and closed by screwing the plug 17a, 17b in and out through the housing 19 of the flow control device 3.
  • the orifice 18a, 18b is in the figure shown as an opening in the base pipe 2.
  • the respective plug 17a, 17b has further an end stop to prevent detachment from the flow control device 3.
  • the orifice 18a, 18b is more specifically arranged in an opening in the second base pipe part 2b that is extending at the inside of the inlet control valve 3.
  • the port 15a, 15b may however have other designs than a threaded plug 17a, 17b and orifice 18a, 18b. Any devices able to provide a fast, practical and robust on/off functionality will be possible embodiments for the port assembly in the inlet control device 3.
  • a preferable alternative over the manually operated port as described above, is to arrange a similar actuator arrangement as disclosed in the first embodiment in connection with each of the ports 15a, 15b to open or close these ports remotely.
  • the actuators are further communicating with a control device and further to a control panel or display to be operated wirelessly by personnel at the installation surface in a similar way as the first embodiment. This is preferably performed in a two way wireless communication.
  • Figure 7a-figure 7b shows two possible embodiments of the inlet and outlet check valves 16a, 16b of the inlet control device 3. Both embodiments show check valves allowing flow in one direction only.
  • the check valves may be used in all embodiments described in figure 3-5 and figure 6.
  • the check valves 16a’, 16b’ are separated for injection and production. There is in this embodiment thus arranged two set of ports 15a, 15b, one to each flow path.
  • This embodiment is equal to the embodiment illustrated in figure 6 and disclosed above.
  • the check valve is here a ball arranged in the respective inlet and outlet channels, to allow flow in one direction and prevent flow in the other direction.
  • the inlet and outlet are combined in one unit but have separate flow path through the flow control 3, 50. There are also separate sets of ports fluidly connected to each of the flow path. In a similar way as in the embodiment of figure 7a.
  • the production fluid and treatment fluid are guided through different valves or openings into and out of the housing 19, 51 of the flow control device 3, 50.
  • the inlet and outlet are shown as a channel with vertical flaps in each outlet/inlet. The vertical flaps are adapted to move out of the vertical position in opposite directions as shown in figure 7b.
  • check valves than the shown examples or inlet/outlet arrangement may be used as long as they are implementing a robust device with low pressure differential.
  • the flow control device 3, 50 may, as mention above, have a plurality of independent flow paths, for production and for injection. Each flow path is equipped with a number of ports 15a, 15b or openings 57 in parallel that can be opened or closed prior to installation.
  • the production path P flows from the formation 1 1 or screen joint 4 through the check valve 16a, 16a’ 16a” and one or more ports 15b1 , 15b2, ..15bn in the flow control device 3.
  • the injection path I flows from the tubular line 1 through the ports 15a and the check valve 16a to the screen joint 4 or formation 11.
  • the partial flow paths are referred to 11 , I2, I3... In.
  • the production path has a number of ports 15b1 , 15b2 etc for flow adjustment in addition to a large diameter port 15n for fully open position.
  • the stimulation scenario is more predictable but will require a large variation of choking along the well.
  • the injection path I also has a number of ports 15a1 , 15a2 etc and one port 15an for fully open.
  • Both the production and injection flow paths P, I respectively is equipped with the check valve 16a, 16b that allows flow only in the intended direction.
  • This illustrated flow path could also illustrate the flow path of the control device according to the embodiment in figure 3-5.
  • the nozzle is then illustrating the orifices 52a, 52b and the production/injection arrow flows to an opening and further into the tubular line 1.
  • the flow control device 3, 50 according to the invention is thus adjustable and each flow control device 3,50 arranged in each tubular segment 5 may be varied independently and remotely by a wireless communication with the attached actuator.
  • the flow control may be adjusted to the requirements in different zones in the well.
  • An operator uses a control panel to set the conditions of the flow control, remotely. This is performed by wireless communication between the control panel and a control device in the flow control, preferably by two-way communication signals.
  • the control device 61 will thus operate a valve opener 54, 15a, 15b to set the flow rate through the flow control device 3, 50.
  • the control device may set bot flow rate into the tubular line and out of the tubular line in the same flow control device 3, 50.
  • the total length and number of tubular segment 5 between packers 6 and formation quality may be different from what was used to design the number of ports or orifices and port 15b or orifice diameters.
  • the flow control device 3, 50 according to the figures will be adjustable on site with up to a number of adjustments. A plurality of number are possible, for instance 2, 3 or 8 as illustrated in the embodiments. One of these adjustments will be reserved for fully open as disclosed above. Fully closed valve will be obtained by closing all the ports 15b, 52a, 52b. The adjustment will take sufficiently small time to perform on site. It will not require any parts to be removed.
  • the flow control device 3, 50 does not need to be disassembled. This feature can provide the following added flexibility:
  • Adjustments for unexpected zone length or formation quality can be handled by varying the adjustment within number of intermediate settings.
  • the fully closed position can also be used for the individual flow control devices in the respective tubular segments 5 to provide less flow control device 3, 50 flow area and more aggressive choking for a specific zone.
  • the fully open position can be used if no choking is required.
  • the respective flow control devices 3 for a specific well 10 will arrive at the rig with preset settings according to the planned well design. If changes are required, this will preferentially take place on the pipe deck prior to installation by the wireless communication between the control panel operated by the operator and the control device arranged remotely, integrated in the flow control device 3, 50. However, last minute changes could also take place on the drill floor due to the simplicity of the operation.
  • the operation of the tubular line 1 with the flow control device 3 in an injection mode may in a similar way be adjusted by adjusting how many of the ports 15a or orifices 52a, 52b in connection with the injection path I that are to be closed/open to obtain the desired flow through the flow control device 3.
  • Figure 9 shows a simulation of the oil production potential from applying the well data to adjust the flow control device at the time of installation.
  • the example is illustrating an example from North Sea well producing with a maximum liquid production rate of 2000 Sm3/d in a sand stone formation with variable reservoir quality.
  • the well has considerable water influx in the high permeability zones.
  • Figures 10 and 1 1 illustrates the effect of the flow control device 3 according to the invention compared to a regular flow device in a diagram.
  • the simulations were performed with acid stimulation in figure 10 and a scale squeeze in figure 1 1 .
  • the fluids were simulated in a reservoir/well simulator with post processing in a dynamic wellbore model.
  • the comparison is between stimulation through tubular line 1 with flow control devices chosen for optimal production (one 4 mm nozzle per joint) and a tubular line 1 where an increasing percentage of the flow control devices 3 flow area is closed for injection towards the heel of the wellbore (fewer nozzles activated for injection than production).
  • the table below defines the tubular line 1 divided into 16 zones.
  • the table further defines how large percent of the ports 15a1 , 15a2,.. 15b1 , 15b2..or orifices 52a, 52b that are open for each zone in the simulation of treatment through control devices according to the present invention.
  • the wellbore has initially a skin of 100 to emulate damage and mud cake, except along the first 1000 m, where skin is reduced to 10 to emulate the acid initially working on the filter cake along the heel part.
  • Figure 10 illustrates the resulting annulus acid coverage for the two cases after 1 1/2 hours of pumping 1000 l/min.
  • the acid coverage is given as number of annulus volumes placed at a certain location.
  • the case with the flow control device according to the invention achieves a significantly better distribution of acid towards the toe of the well.
  • the well has a skin of 3 along the entire wellbore, and the treatment is bullheaded with a pump rate of 1000 l/min.
  • the same flow control device and check valve configuration was used for this case. It is seen in figure 1 1 that the flow control device configurations according to the invention places significantly more of the treatment fluid towards the toe of the well.

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  • General Life Sciences & Earth Sciences (AREA)
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Abstract

L'invention concerne un dispositif de régulation de débit (3) destiné à être utilisé dans un tuyau tubulaire (1) dans un puits de pétrole et de gaz (10), comprenant un boîtier (19, 51), au moins une ouverture (18a, 18b, 57) s'étendant radialement à travers le boîtier entre un réservoir à l'extérieur du tuyau tubulaire (1) et un intérieur (30) du boîtier (19, 51) lorsqu'il est utilisé dans le tuyau tubulaire (1). Le dispositif de régulation de débit (3, 50) comprend en outre un agencement d'actionneur actionné sans fil et alimenté électriquement (53) conçu pour positionner un régulateur de soupape (54, 15a, 15b) afin de régler la quantité d'écoulement conçue pour s'écouler à travers ladite ouverture (18a, 18b, 57) avant l'installation dans le puits (10), et un clapet de non-retour (16a, 16b) disposé en liaison avec ladite ouverture (18a, 18b, 57), pour régler respectivement une direction d'écoulement à travers chacune desdites ouvertures (18a, 18b, 57). L'invention comprend en outre une ligne tubulaire comprenant la commande d'écoulement et un procédé de réglage de la production et du fonctionnement de traitement d'un puits.
PCT/EP2020/062911 2019-05-08 2020-05-08 Dispositif de régulation de débit souple WO2020225432A1 (fr)

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NO20190582A NO346128B1 (en) 2019-05-08 2019-05-08 Flow control device and method for well operations
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WO2014123539A1 (fr) * 2013-02-08 2014-08-14 Halliburton Energy Services, Inc. Dispositif de régulation de débit entrant à commande électronique
WO2014123540A1 (fr) * 2013-02-08 2014-08-14 Halliburton Energy Services, Inc. Ensemble vanne pouvant être activé sans fil
WO2017058255A1 (fr) * 2015-10-02 2017-04-06 Halliburton Energy Services, Inc. Outils de commande de fond de trou actionnés à distance et multifonctionnels
US20180106137A1 (en) * 2016-04-29 2018-04-19 Halliburton Energy Services, Inc. Water front sensing for electronic inflow control device
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US20180283134A1 (en) * 2016-12-27 2018-10-04 Halliburton Energy Services, Inc. Flow control devices with pressure-balanced pistons

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US5435393A (en) 1992-09-18 1995-07-25 Norsk Hydro A.S. Procedure and production pipe for production of oil or gas from an oil or gas reservoir
WO2014123539A1 (fr) * 2013-02-08 2014-08-14 Halliburton Energy Services, Inc. Dispositif de régulation de débit entrant à commande électronique
WO2014123540A1 (fr) * 2013-02-08 2014-08-14 Halliburton Energy Services, Inc. Ensemble vanne pouvant être activé sans fil
US20140262321A1 (en) 2013-02-08 2014-09-18 Halliburton Energy Services, Inc. Wireless Activatable Valve Assembly
WO2017058255A1 (fr) * 2015-10-02 2017-04-06 Halliburton Energy Services, Inc. Outils de commande de fond de trou actionnés à distance et multifonctionnels
US20180106137A1 (en) * 2016-04-29 2018-04-19 Halliburton Energy Services, Inc. Water front sensing for electronic inflow control device
US20180155991A1 (en) * 2016-12-06 2018-06-07 Saudi Arabian Oil Company Well completion system
US20180283134A1 (en) * 2016-12-27 2018-10-04 Halliburton Energy Services, Inc. Flow control devices with pressure-balanced pistons

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