WO2024244359A1 - 连续管井口悬挂、井底封堵完井管柱的施工方法 - Google Patents

连续管井口悬挂、井底封堵完井管柱的施工方法 Download PDF

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Publication number
WO2024244359A1
WO2024244359A1 PCT/CN2023/136160 CN2023136160W WO2024244359A1 WO 2024244359 A1 WO2024244359 A1 WO 2024244359A1 CN 2023136160 W CN2023136160 W CN 2023136160W WO 2024244359 A1 WO2024244359 A1 WO 2024244359A1
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WIPO (PCT)
Prior art keywords
coiled tubing
wellhead
tubing
pressure
well
Prior art date
Legal status (The legal status 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 status listed.)
Ceased
Application number
PCT/CN2023/136160
Other languages
English (en)
French (fr)
Inventor
吕维平
张炎
付悦
刘家炜
任彬
周士杰
张正
祝叶
辛永安
贾夏
陈智
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
China National Petroleum Corp
CNPC Engineering Technology R&D Co Ltd
CNPC Jianghan Machinery Research Institute Co Ltd
Original Assignee
China National Petroleum Corp
CNPC Engineering Technology R&D Co Ltd
CNPC Jianghan Machinery Research Institute Co Ltd
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Filing date
Publication date
Application filed by China National Petroleum Corp, CNPC Engineering Technology R&D Co Ltd, CNPC Jianghan Machinery Research Institute Co Ltd filed Critical China National Petroleum Corp
Publication of WO2024244359A1 publication Critical patent/WO2024244359A1/zh
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

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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
    • E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or 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
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • 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
    • E21B29/00—Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
    • 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
    • E21B29/00—Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
    • E21B29/002—Cutting, e.g. milling, a pipe with a cutter rotating along the circumference of the pipe
    • 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
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof
    • E21B33/04—Casing heads; Suspending casings or tubings in well heads
    • 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
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof
    • E21B33/04—Casing heads; Suspending casings or tubings in well heads
    • E21B33/0422—Casing heads; Suspending casings or tubings in well heads a suspended tubing or casing being gripped by a slip or an internally serrated member
    • 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
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof
    • E21B33/068—Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells

Definitions

  • the invention relates to the technical field of natural gas well completion, and in particular to a construction method for a continuous tubing wellhead suspension and well bottom plugging completion pipe string.
  • patent CN105064940B discloses a built-in coiled tubing completion string and construction method.
  • the string includes a built-in hanger, a coiled tubing, a plug and a plugging rod.
  • the process sequence is to install the built-in hanger in the tubing head, lower the pipe to the designed position once, temporarily hang the coiled tubing shear pipe to install the locking type seat hanging joint, lower the pipe for the second time to seat the joint together with the coiled tubing into the hanger body, and then restore the wellhead gas production tree to complete the coiled tubing completion string for production.
  • Patent CN115162999A discloses a large-diameter continuous gas production string delivery construction method.
  • the process sequence is to lower the pipe to the designed position once, temporarily hang the shear pipe, connect the coiled tubing with the tubing hanger, lower the pipe for the second time to seat the tubing hanger to the wellhead, and then restore the wellhead gas production tree to complete the coiled tubing completion string for production.
  • the above method is also the most widely used coiled tubing completion string process in oil fields and on the market. There are two problems with both completion processes:
  • the coiled tubing is in a temporary suspension state. At this time, the coiled tubing is only suspended by the wellhead blowout prevention equipment, which has high safety performance requirements for the wellhead blowout prevention equipment. If the equipment suspension function fails, the coiled tubing will directly fall into the well and cause an accident. Therefore, this process has a great safety hazard;
  • the purpose of the present invention is to overcome the risk problem caused by temporary suspension of coiled pipe in the prior art.
  • the present invention provides a construction method for a coiled tubing wellhead suspension and well bottom plugging completion string, wherein the construction method comprises:
  • the wellhead equipment from top to bottom includes the injection head, blowout preventer box, four-gate blowout preventer, blowout preventer, pressure relief tee and operation window;
  • a slip tooth is provided on the inner circumferential surface of the suspension slip
  • the outer circumferential surface of the suspension slip is formed as a tapered surface from top to bottom
  • the inner circumferential surface of the upper end of the tubing hanger is formed as a tapered surface from top to bottom to accommodate and suspend the suspension slip.
  • the suspension slip includes two semi-tubular portions and a connector for detachably connecting the two semi-tubular portions.
  • the tubing hanger is sealingly engaged with the wellhead spool, and the tubing hanger is fixed by a top screw of the wellhead spool.
  • the replacement of the wellbore tool string for the completion tubing string includes: opening the operation window, disassembling the wellbore tool string for well cleaning, installing a dropper, a packer, and a plugger at the lower end of the continuous tubing, and hanging the tubing hanger on the packer.
  • the inside of the tubing is pressurized so that the packer is set at a designed position, and the coiled tubing is continued to be lowered to release a portion of the suspended weight of the injection head.
  • S3 further includes: opening the pressure relief tee and controlling the blowout through the ground throttle manifold to release the upper pressure of the packer, filling the annulus area with packer fluid, so that there is no pressure at the wellhead.
  • continuing to lower the coiled tubing to the designed depth includes: lowering the coiled tubing at a speed not exceeding 5 m/min, and observing the operation of the equipment when the lowering depth reaches 50 m; then continuing to lower the coiled tubing at a speed of 25-30 m/min, and performing a lifting and hanging weight test every 500 m during the lowering process; when the coiled tubing is lowered to 300 m from the designed depth, reducing the speed to 10-15 m/min, and when the coiled tubing is lowered to 100 m from the designed depth, reducing the speed to 5 m/min, and lifting it to the designed depth after passing the designed depth of 15 m.
  • the gate switch function of the four-gate blowout preventer is tested to be in the fully open position, and then the injection head, the blowout preventer box, the four-gate blowout preventer, the pressure relief tee, the blowout preventer, and the operating window are installed and connected to the ground high-pressure pump group pipeline to perform pressure tests on the ground pipeline and wellhead equipment.
  • the pressure test requires increasing the pump pressure stepwise by 10%, 50%, and 100% to 35 MPa, and is qualified if the pressure is stabilized for 10 minutes and the pressure drop is less than 0.7 MPa. If a leak is found, the pump is immediately stopped to release the pressure for rectification.
  • the coiled tubing is passed through the injection head and lowered to the position of the operation window; the operation window is opened, the lower end of the coiled tubing is chamfered, a connector is installed, and a tensile test is performed;
  • the motor head and well cleaning tools are installed at the lower end, the operation window is closed, and the wellhead equipment is pressure tested through the surface high-pressure pump group pipeline; the flat valve is opened, the coiled tubing is lowered to the designed depth, and the surface high-pressure pump group pipeline is opened to complete the well cleaning operation in the designed area.
  • the lower end of the coiled tube is chamfered at 45°; the connector is subjected to a 15-ton tensile test, and a displacement of less than 3-5 mm is considered qualified.
  • the operating window is opened, and the hanging slips are installed to the outer wall of the coiled tubing and close to the upper part of the tubing hanger; the coiled tubing is continued to be lowered, and the hanging slips fall into the tubing hanger, and the coiled tubing is continued to be lowered until the hanging weight of the injection head is zero and the coiled tubing has no slippage and no abnormal load, and then the shear ram of the four-ram blowout preventer is used to shear the coiled tubing, lift the coiled tubing, and observe the load and pressure changes of the injection head to verify whether the shearing is successful.
  • a No. 1 liner and a No. 2 liner are installed in the gas tree, the gas tree is assembled, and the main valve of the gas tree is closed; the plug of the plugging device is removed by pressurizing the pipeline of the ground high-pressure pump group, and then the well is shut in.
  • FIG. 2 Schematic diagram of the coiled tubing completion string process wellhead device
  • FIG. 3 Schematic diagram of the wellhead process of the coiled tubing completion string process
  • FIG. 4 Schematic diagram of coiled tubing well cleaning tool string
  • FIG. 5 Schematic diagram of coiled tubing completion tool string
  • FIG. 7 Schematic diagram of coiled tubing wellhead suspension process
  • This solution provides a construction method for a coiled tubing wellhead suspension and well bottom plugging completion string, wherein the construction method comprises:
  • the tubing hanger 3 is movably arranged on the coiled tubing 1, so when the coiled tubing 1 is lowered, the tubing hanger 3 can be dropped onto the wellhead spool 15 to be sealed; as shown in FIGS. 6 and 7 , the hanging slips 2 are fixed on the coiled tubing 1, and can be held in the tubing hanger 3 as the coiled tubing 1 moves downward, thereby hanging the coiled tubing 1 on the tubing hanger 3, thereby solving the risks caused by temporary hanging.
  • the inner circumference of the hanging slip 2 is provided with a slip tooth 2-1
  • the outer circumference of the hanging slip 2 is formed as a tapered surface from top to bottom
  • the inner circumference of the upper end of the tubing hanger 3 is formed as a tapered surface from top to bottom to accommodate and hang the hanging slip 2.
  • the hanging slip 2 is engaged with the outer wall of the coiled tubing 1 through the slip tooth 2-1, and the outer circumference is matched with the inner circumference of the tubing hanger 3 to axially support the hanging slip 2 upward through the tubing hanger 3.
  • the hanging slip 2 hangs the coiled tubing 1 at the wellhead through the tubing hanger 3.
  • the tubing hanger 3 includes a hanger body 3 - 1 and a sealing assembly 3 - 2 , and the sealing groove on the inner circumference matches with the outer circumference of the suspension slip 2 .
  • the suspension slip 2 includes two semi-tubular parts and a connector for detachably connecting the two semi-tubular parts. As shown in FIG8 , the suspension slip 2 mainly consists of two semi-tubular parts, which are detachably connected by a connector. With such a structure, it is convenient to install the suspension slip 2 on the continuous pipe 1.
  • the tubing hanger 3 is sealed and engaged with the wellhead spool 15, and the tubing hanger 3 is fixed by the top screw of the wellhead spool 15. As shown in FIG14 , the tubing hanger 3 is arranged in the wellhead spool 15, and its outer periphery is sealed and engaged with the inner periphery of the wellhead spool 15 to achieve sealing. The wellhead spool 15 is pressed against the tubing hanger 3 by the radial top screw to achieve relative tightness. fixed.
  • the replacement of the well-entry tool string for the completion string includes: opening the operation window 13, disassembling the well-entry tool string for cleaning the well, installing the release hand 5, the packer 6, and the plug 7 at the lower end of the coiled tubing 1, and hanging the tubing hanger 3 on the packer 6, as shown in Figure 5.
  • the release hand 5, the packer 6, and the plug 7 are the completion tool string, and after the well-entry tool string is disassembled through the operation window 13, the completion tool string is installed at the lower end of the coiled tubing 1.
  • the release 5 adopts a mechanical release structure, which includes an upper joint 5-1, a pin 5-2 and a lower joint 5-3 from top to bottom, and is installed between the connector 4 and the packer 6.
  • the pin 5-2 is cut off by lifting the tubing string to achieve the release operation of the coiled tubing 1.
  • the packer 6 is installed between the release hand 5 and the plugging device 7 , and the continuous pipe 1 and the casing annulus channel at the position of the packer 6 can be plugged by pressurizing the inside of the pipe.
  • the plug 7 adopts a functional integrated design, and includes a double-flap back-pressure valve 7-1, a plug 7-2, a screen 7-3, and a guide head 7-4 from top to bottom.
  • the double-flap back-pressure valve 7-1 is located at the front end of the plug 7-2, and is constrained by the control sleeve to be in an open state.
  • the control sleeve is knocked off by throwing a ball, and the double-flap back-pressure valve 7-1 is started to realize the pressure-lifting of the pipe.
  • the plug 7-2 is placed at the end of the plug 7 to achieve the internal sealing of the pipe.
  • the fixed pin is sheared off by pressure and the plug 7-2 is pumped down for production.
  • the screen 7-3 is located at the lower end of the functional area of the plug 7, and adopts a grid-shaped design.
  • the grid spacing can be adjusted according to production needs.
  • the guide head 7-4 is located at the tail end of the plug 7, connected to the screen 7-3, and fixed by the rivets.
  • the packer 6 is set at the designed position by pressurizing the inside of the tubing, and the coiled tubing 1 is further lowered to release a portion of the hanging weight of the injection head 8.
  • the packer 6 is set on the casing by pressurizing the inside of the coiled tubing 1, and the coiled tubing 1 is further lowered, thereby releasing a portion of the hanging weight of the injection head 8.
  • the packer 6 can realize the plugging of the downhole annulus by the coiled tubing as a completion string, and the development of a specific production layer section can be carried out.
  • step S3 also includes: opening the pressure relief tee 12 and controlling the blowout through the surface throttle manifold to release the pressure on the upper part of the packer 6, filling the annular area with packer fluid, and making the wellhead pressure-free.
  • the packer fluid is injected into the annular area to protect the casing and the production string and the wellhead from pressure-induced safe operation.
  • the continuous lowering of the coiled tube 1 to the designed depth includes: lowering the coiled tube 1 at a speed not exceeding 5m/min, observing the operation of the equipment when the lowering depth reaches 50m; then continuing to lower the coiled tube 1 at a speed of 25m/min, and performing a lifting and hanging weight test every 500m during the lowering process; when it is lowered to 300m from the designed depth, the speed is reduced to 10m/min, and when it is lowered to 100m from the designed depth, the speed is reduced to 5m/min, and after the designed depth exceeds 15m, it is lifted to the designed depth.
  • lowering the coiled tube 1 first lower the tube at a lower speed, then lower the tube at a higher speed, and perform a hanging weight test, and finally lower the tube at a lower speed, and lift it up after the lowered depth exceeds the designed depth.
  • the switch function of each gate of the four-gate blowout preventer 10 is tested to make it in the fully open position, and then the injection head 8, the blowout preventer box 9, the four-gate blowout preventer 10, the pressure relief tee 12, the blowout preventer 11, and the operation window 13 are installed, and connected to the ground high-pressure pump group pipeline to perform pressure testing on the ground pipeline and wellhead equipment respectively.
  • the pressure test is performed through the ground high-pressure pump group pipeline (refer to Figure 3) to detect whether there is a leak.
  • the pressure test requires that the pump pressure be increased step by step by 10%, 50%, and 100% to 35MPa, and the pressure must be maintained for 10 minutes and the pressure drop must be less than 0.7MPa to be qualified. If a leak is found, the pump must be stopped immediately to release the pressure and rectify the problem. During the pressure test, the pressure is increased step by step. When the maximum pressure is reached, the corresponding pressure must be maintained for a certain period of time. If there is a leak, rectification and repair are required.
  • the coiled tube 1 is passed through the injection head 8 and lowered to the position of the operation window 13; the The operation window 13 is opened, the lower end of the coiled tubing 1 is chamfered, the connector 4 is installed, and a tensile test is performed; as shown in FIG4 , a motor head 16 and a well-flushing tool 17 are installed at the lower end of the connector 4, the operation window 13 is closed, and the wellhead equipment is pressure tested through the ground high-pressure pump group pipeline; the flat valve 14 is opened, the coiled tubing 1 is lowered to the designed depth, and the ground high-pressure pump group pipeline is opened to complete the well-flushing operation in the designed area.
  • the connector 4 adopts a rubber sleeve seal design, which includes a slip connection 4-1 and a rubber sleeve seal 4-2 from top to bottom, and is installed at the bottom of the coiled tubing 1 so that the coiled tubing 1 can be connected to the downhole tool assembly.
  • the lower end of the coiled tube 1 is chamfered by 45°; the connector 4 is subjected to a 15t tensile test, wherein the displacement is less than 3-5mm and is considered qualified.
  • the coiled tube 1 is chamfered to facilitate connection with the connector 4; the connector 4 is subjected to a tensile test to confirm its connection strength.
  • the operation window 13 is opened, and the hanging slip 2 is installed on the outer wall of the coiled tubing 1 and close to the upper part of the tubing hanger 3; the coiled tubing 1 is continued to be lowered, and the hanging slip 2 falls into the tubing hanger 3, and the coiled tubing 1 is continued to be lowered until the hanging weight of the injection head 8 is zero and the coiled tubing 1 has no slippage and no abnormal load, and the shear ram of the four-ram blowout preventer 10 is used to cut the coiled tubing 1, and the coiled tubing 1 is lifted and the load and pressure changes of the injection head 8 are observed to verify whether the pipe cutting is successful.
  • the coiled tubing 1 is lowered, so that the hanging slip 2 is suspended on the tubing hanger 3, and the coiled tubing 1 is continued to be lowered, so that the downward pulling force of the coiled tubing 1 on the injection head 8 is zero, and the coiled tubing 1 is cut; the coiled tubing 1 above the shearing position is lifted to determine whether the coiled tubing 1 is cut.
  • No. 1 liner and No. 2 liner are installed in the gas tree 18, the gas tree 18 is assembled, and the main valve of the gas tree 18 is closed; the plug 7-2 of the plug 7 is knocked out by the ground high-pressure pump group pipeline, and the well is shut in.
  • the gas tree 18 includes a multi-section structure. Before connecting the multi-section structure, No. 1 liner 18-1 and No. 2 liner 18-2 are installed therein, so that No. 1 liner 18-1 and No.
  • This solution provides a construction method for a coiled tubing wellhead suspension and well bottom plugging completion string, wherein the construction method comprises:
  • the tubing hanger 3 is movably arranged on the coiled tubing 1, so that when the coiled tubing 1 is lowered, the tubing hanger 3 can be moved.
  • the tubing hanger 3 falls onto the wellhead spool 15 and is sealed; as shown in FIGS. 6 and 7 , the hanging slips 2 are fixed on the coiled tubing 1 and can be held in the tubing hanger 3 as the coiled tubing 1 moves downward, thereby hanging the coiled tubing 1 on the tubing hanger 3, thereby solving the risks caused by temporary suspension.
  • the inner circumference of the hanging slip 2 is provided with a slip tooth 2-1
  • the outer circumference of the hanging slip 2 is formed as a tapered surface from top to bottom
  • the inner circumference of the upper end of the tubing hanger 3 is formed as a tapered surface from top to bottom to accommodate and hang the hanging slip 2.
  • the hanging slip 2 is engaged with the outer wall of the coiled tubing 1 through the slip tooth 2-1, and the outer circumference is matched with the inner circumference of the tubing hanger 3 to axially support the hanging slip 2 upward through the tubing hanger 3.
  • the hanging slip 2 hangs the coiled tubing 1 at the wellhead through the tubing hanger 3.
  • the tubing hanger 3 includes a hanger body 3 - 1 and a sealing assembly 3 - 2 , and the sealing groove on the inner circumference matches with the outer circumference of the suspension slip 2 .
  • the suspension slip 2 includes two semi-tubular parts and a connector for detachably connecting the two semi-tubular parts. As shown in FIG8 , the suspension slip 2 mainly consists of two semi-tubular parts, which are detachably connected by a connector. With such a structure, it is convenient to install the suspension slip 2 on the continuous pipe 1.
  • the tubing hanger 3 is sealed and engaged with the wellhead spool 15, and the tubing hanger 3 is fixed by the top screw of the wellhead spool 15. As shown in FIG14 , the tubing hanger 3 is arranged in the wellhead spool 15, and its outer periphery is sealed and engaged with the inner periphery of the wellhead spool 15 to achieve sealing.
  • the wellhead spool 15 is relatively fixed by tightening the tubing hanger 3 with radial top screws.
  • the replacement of the well-entry tool string for the completion string includes: opening the operation window 13, disassembling the well-entry tool string for cleaning the well, installing the release hand 5, the packer 6, and the plug 7 at the lower end of the coiled tubing 1, and hanging the tubing hanger 3 on the packer 6, as shown in Figure 5.
  • the release hand 5, the packer 6, and the plug 7 are the completion tool string, and after the well-entry tool string is disassembled through the operation window 13, the completion tool string is installed at the lower end of the coiled tubing 1.
  • the release 5 adopts a mechanical release structure, which includes an upper joint 5-1, a pin 5-2 and a lower joint 5-3 from top to bottom, and is installed between the connector 4 and the packer 6.
  • the pin 5-2 is cut off by lifting the tubing string to achieve the release operation of the coiled tubing 1.
  • the packer 6 is installed between the release hand 5 and the plugging device 7 , and the continuous pipe 1 and the casing annulus channel at the position of the packer 6 can be plugged by pressurizing the inside of the pipe.
  • the plug 7 adopts a functional integrated design, and includes a double-flap back-pressure valve 7-1, a plug 7-2, a screen 7-3, and a guide head 7-4 from top to bottom.
  • the double-flap back-pressure valve 7-1 is located at the front end of the plug 7-2, and is constrained by the control sleeve to be in an open state.
  • the control sleeve is knocked off by throwing a ball, and the double-flap back-pressure valve 7-1 is started to realize the pressure-lifting of the pipe.
  • the plug 7-2 is placed at the end of the plug 7 to achieve the internal sealing of the pipe.
  • the fixed pin is sheared off by pressure and the plug 7-2 is pumped down for production.
  • the screen 7-3 is located at the lower end of the functional area of the plug 7, and adopts a grid-shaped design.
  • the grid spacing can be adjusted according to production needs.
  • the guide head 7-4 is located at the tail end of the plug 7, connected to the screen 7-3, and fixed by the rivets.
  • the packer 6 is set at the designed position by pressing the inside of the tubing, and the coiled tubing 1 is further lowered to release a portion of the hanging weight of the injection head 8.
  • the packer 6 is set on the casing by pressing the inside of the coiled tubing 1, and the coiled tubing 1 is further lowered, thereby releasing a portion of the hanging weight of the injection head 8.
  • the packer 6 can realize the use of the coiled tubing as a completion string for the downhole well. The sealing of the annulus allows the development of specific production intervals.
  • step S3 also includes: opening the pressure relief tee 12 and controlling the blowout through the surface throttle manifold to release the pressure on the upper part of the packer 6, filling the annular area with packer fluid, and making the wellhead pressure-free.
  • the packer fluid is injected into the annular area to protect the casing and the production string and the wellhead from pressure-induced safe operation.
  • the continuous lowering of the coiled tube 1 to the designed depth includes: lowering the coiled tube 1 at a speed not exceeding 5m/min, observing the operation of the equipment when the lowering depth reaches 50m; then continuing to lower the coiled tube 1 at a speed of 30m/min, and performing a lifting and hanging weight test every 500m during the lowering process; when it is 300m away from the designed depth, reducing the speed to 15m/min, and when it is 100m away from the designed depth, reducing the speed to 5m/min, and lifting it to the designed depth after the designed depth of 15m is exceeded.
  • lowering the coiled tube 1 first lower the tube at a lower speed, then lower the tube at a higher speed, and perform a hanging weight test, and finally lower the tube at a lower speed, and lift it up after the lowered depth exceeds the designed depth.
  • the switch function of each gate of the four-gate blowout preventer 10 is tested to make it in the fully open position, and then the injection head 8, the blowout preventer box 9, the four-gate blowout preventer 10, the pressure relief tee 12, the blowout preventer 11, and the operation window 13 are installed, and connected to the ground high-pressure pump group pipeline to perform pressure testing on the ground pipeline and wellhead equipment respectively.
  • the pressure test is performed through the ground high-pressure pump group pipeline to detect whether there is a leak.
  • the pressure test requires that the pump pressure be increased step by step by 10%, 50%, and 100% to 35MPa, and the pressure must be maintained for 10 minutes and the pressure drop must be less than 0.7MPa to be qualified. If a leak is found, the pump must be stopped immediately to release the pressure and rectify the problem. During the pressure test, the pressure is increased step by step. When the maximum pressure is reached, the corresponding pressure must be maintained for a certain period of time. If there is a leak, rectification and repair are required.
  • the coiled tube 1 is passed through the injection head 8 and lowered to the position of the operation window 13; the operation window 13 is opened, the lower end of the coiled tube 1 is chamfered, the connector 4 is installed, and a tensile test is performed; as shown in FIG4, a motor head 16 and a well-flushing tool 17 are installed at the lower end of the connector 4, the operation window 13 is closed, and the wellhead equipment is pressure tested through the ground high-pressure pump group pipeline; the flat valve 14 is opened, the coiled tube 1 is lowered to the designed depth, and the ground high-pressure pump group pipeline is opened to complete the well-flushing operation of the designed area.
  • the connector 4 adopts a rubber sleeve seal design, which includes a slip connection 4-1 and a rubber sleeve seal 4-2 from top to bottom, and is installed at the bottom of the coiled tube 1, so that the coiled tube 1 can be connected to the downhole tool assembly.
  • the lower end of the coiled tube 1 is chamfered by 45°; the connector 4 is subjected to a 15t tensile test, wherein the displacement is less than 3-5mm and is considered qualified.
  • the coiled tube 1 is chamfered to facilitate connection with the connector 4; the connector 4 is subjected to a tensile test to confirm its connection strength.
  • the operation window 13 is opened, and the hanging slip 2 is installed on the outer wall of the coiled tubing 1 and close to the upper part of the tubing hanger 3; the coiled tubing 1 is continued to be lowered, and the hanging slip 2 falls into the tubing hanger 3, and the coiled tubing 1 is continued to be lowered until the hanging weight of the injection head 8 is zero and the coiled tubing 1 has no slippage and no abnormal load, and the shear ram of the four-ram blowout preventer 10 is used to cut the coiled tubing 1, and the coiled tubing 1 is lifted and the load and pressure changes of the injection head 8 are observed to verify whether the pipe cutting is successful.
  • the coiled tubing 1 is lowered, so that the hanging slip 2 is suspended on the tubing hanger 3, and the coiled tubing 1 is continued to be lowered, so that the downward pulling force of the coiled tubing 1 on the injection head 8 is zero, and the coiled tubing 1 is cut; the coiled tubing 1 above the shearing position is lifted to determine whether the coiled tubing 1 is cut.
  • No. 1 liner and No. 2 liner are installed in the gas tree 18, the gas tree 18 is assembled, and the main valve of the gas tree 18 is closed; the plug 7-2 of the plug 7 is pressed off by the pipeline of the ground high-pressure pump group, and the well is shut in.
  • the gas production The tree 18 includes a multi-section structure. Before connecting the multi-section structure, No. 1 liner 18-1 and No. 2 liner 18-2 are installed therein so that No. 1 liner 18-1 and No. 2 liner 18-2 are docked with the continuous pipe 1. Then the multi-section structure is connected, and the main valve of the gas production tree 18 is closed; the pipeline of the ground high-pressure pump group is pressurized to knock out the plug 7-2 of the plug 7, connect the reservoir and the continuous pipe 1, and shut down the well.
  • the method for constructing a coiled tubing wellhead suspension and well bottom plugging completion string includes the following steps:
  • Step 1 Arrange the coiled tubing equipment according to the recommended practice for coiled tubing operation in oil and gas wells, dismantle the original wellhead device, and only keep the flat valve 14. Test the switch function of each gate of the four-gate blowout preventer 10 to make it fully open. As shown in Figure 2, install the injection head 8, blowout preventer box 9, four-gate blowout preventer 10, pressure relief tee 12, blowout preventer 11, and operation window 13 on the flat valve 14. As shown in Figure 3, connect the ground pipeline, and test the ground high-pressure pump group pipeline and wellhead respectively. The pressure test requires increasing the pump pressure to 35MPa step by step by 10%, 50%, and 100%, and stabilizing the pressure for 10 minutes. The pressure drop is less than 0.7MPa for passing. If leakage is found, stop the pump immediately to relieve the pressure and rectify.
  • Step 2 Pass the coiled tube 1 through the injection head 8 and lower it to the position of the operating window 13. Open the operating window 13, chamfer the lower end of the coiled tube 1, and install the connector 4. During the installation of the connector 4, the lower end of the coiled tube 1 is chamfered at 45° to ensure that the coiled tube 1 is vertical as much as possible to avoid damaging the sealing ring during installation. After the installation is completed, a tensile test is performed. The tensile test is 15t, and the displacement is less than 3-5mm to be qualified. As shown in Figure 4, install the motor head 16 and the well cleaning tool 17 at the lower end of the connector 4, close the operating window 13, and test the pressure of the wellhead equipment through the ground high-pressure pump group pipeline. Open the flat valve 14, lower the pipe to the designed depth, start the ground pump group, complete the well cleaning operation in the designed area, and ensure the cleanliness of the inner wall of the wellbore.
  • Step 3 Lift the coiled tubing 1 to the position of the operating window 13 and close the flat valve 14. Open the operating window 13, remove the motor head 16 and the well cleaning tool 17, install the hand release 5, the packer 6 and the plug 7 at the lower end of the connector 4, hang the tubing hanger 3 on the packer 6, as shown in Figure 5, and put the well tool string into the blowout preventer 11. Close the operating window 13 and test the pressure of the well tool string through the ground high-pressure pump group pipeline. Open the flat valve 14, slowly lower the tubing, and the tubing hanger 3 falls into the wellhead spool 15, and the top screw is fixed to seal. The coiled tubing 1 passes through the tubing hanger 3 and continues to be lowered slowly. The lowering speed does not exceed 5m/min.
  • the lowering depth When the lowering depth reaches 50m, observe the operation of the equipment. After the equipment operates normally, control the lowering speed to be constant and lower the tubing normally. The speed is controlled at 25m/min. During the lowering process, a lifting and hanging weight test is performed every 500m. During the lowering process, pay attention to the change of the pressure of the coiled tubing 1. When it is lowered to 300m from the design depth, the speed is reduced to 10m/min. When it is lowered to 100m from the design depth, the speed is reduced to 5m/min. After the design depth is passed 15m, it is lifted to the design depth. The internal pressure of the pipe is pressurized to make the packer 6 set at the design position.
  • Step 4 As shown in Figure 6, open the operation window 13 and install the hanging slips 2 to the outer wall of the coiled tubing 1 near the upper part of the tubing hanger 3. As shown in Figure 7, lower the coiled tubing 1, and the hanging slips 2 fall into the inner groove of the tubing hanger 3. Continue lowering until the hanging weight of the injection head 8 is zero and the coiled tubing 1 has no slippage and the load is normal. Use the shear gate of the four-gate blowout preventer 10 to shear the tubing, lift the tubing and observe the changes in the load and pressure of the injection head 8 to verify whether the tubing shearing is successful.
  • Step 5 Remove all equipment above the wellhead spool 15, cut off the coiled tubing 1 above the hanging slips 2 with a manual cutter, chamfer the upper end of the coiled tubing 1, and remove the cut neck and burrs.

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Abstract

一种连续管井口悬挂、井底封堵完井管柱的施工方法包括：摆放连续管（1）作业设备，安装井口设备并试压；将连续管穿过注入头（8），安装用于通洗井的入井工具串，进行通洗井作业；更换用于完井管柱的入井工具串，在连续管上设置油管悬挂器（3），下入连续管至设计深度；打开操作窗（13），在连续管上安装悬挂卡瓦（2），下入连续管使得悬挂卡瓦落入油管悬挂器中，割断连续管；移除井口设备，恢复采气树（18），打通堵塞器（7）投产。该方法通过在剪管前预制悬挂卡瓦，避免了井口设备临时悬挂造成的安全隐患。

Description

连续管井口悬挂、井底封堵完井管柱的施工方法
相关申请的交叉引用
本申请要求2023年06月01日提交的中国专利申请202310643960.9的权益，该申请的内容通过引用被合并于本文。
技术领域
本发明涉及天然气井完井技术领域，具体地涉及一种连续管井口悬挂、井底封堵完井管柱的施工方法。
背景技术
随着致密气/页岩气的开发，采用油管柱完井采气带来的产量递减、含水量升高等问题严重影响着气层生产逐渐显现出来；传统的油管带压作业，施工复杂、效率低，现有装备能力可带压作业等级低，价格昂贵；后期井筒积液，常规油管携液差，需要进行辅助工艺进行排液采气生产，增加了开发成本。连续管具备无需接单根、内通径小、完井速度快等优势，相应的特征在速度管柱工艺中亦有体现。将连续管的先天优势应用到致密气/页岩气的开发中，形成连续管完井采气一体化技术，引领推动资源开发的降本提质，施工作业安全高效，在低油价大环境中有着重要的意义。
关于目前已公开的连续管完井管柱工艺，专利CN105064940B公布了一种内置式连续油管完井管柱及施工方法，管柱包括内置式悬挂器、连续管、堵塞器和堵塞杆，工艺顺序采用内置式悬挂器安装于油管头内，一次下管至设计位置，临时悬挂连续管剪管安装锁紧式坐挂接头，二次下管将接头连同连续管坐挂到悬挂器本体内，之后恢复井口采气树，完成连续管完井管柱进行生产。专利CN115162999A公布了一种大直径连续采气管柱投放施工方法，工艺顺序采用一次下管至设计位置，临时悬挂剪管，将连续管与油管悬挂器相连接，二次下管将油管悬挂器坐封至井口，之后恢复井口采气树，完成连续管完井管柱进行生产。上述方式也是目前油田及市场上应用最为广泛的连续管完井管柱工艺，针对这两种完井工艺均存在以下两点问题：
(1)剪管后连续管处于临时悬挂状态，此时连续管仅靠井口防喷设备进行悬挂，对井口防喷设备安全性能要求较高要求，若设备悬挂功能失效，连续管将直接落入井内造成事故，因此该工艺流程存在较大安全隐患；
(2)连续管与井筒之间的环空通道仅靠井口的悬挂器进行密封，井口拆装作业过程中，井口悬挂器处于长期带压状态，若坐封操作不当，存在漏气及上顶风险，威胁井口作业人员。此外，环空长期暴露在生产环境中，套管和生产管柱易发生腐蚀穿孔，影响后续排采作业的进行。
针对上述现有连续管完井工艺存在的问题，结合连续管完井采气一体化工艺的需要，目前缺少符合连续管在井口悬挂，同时实现在井底封堵的安全、高效、经济的完井管柱工艺。
发明内容
本发明的目的是为了克服现有技术存在的连续管临时悬挂所带来的风险的问题。
为了实现上述目的，本发明提供了一种连续管井口悬挂、井底封堵完井管柱的施工方法，其中，所述施工方法包括：
S1、摆放连续管作业设备，安装井口设备并试压，其中，所述井口设备从上至下分别为注入头、防喷盒、四闸板防喷器、防喷管、泄压三通、操作窗；
S2、将连续管穿过所述注入头，安装用于通洗井的入井工具串，下管至设计位置，进行通洗井作业；
S3、提升所述连续管至所述操作窗，更换用于完井管柱的入井工具串，在所述连续管上设置油管悬挂器，下入所述连续管，使得所述油管悬挂器落入井口四通并坐封，继续下入所述连续管至设计深度；
S4、打开所述操作窗，在所述连续管上安装悬挂卡瓦，下入所述连续管使得所述悬挂卡瓦落入所述油管悬挂器中，继续下入至悬重为零后，割断所述连续管；
S5、移除井口设备，恢复采气树，打通堵塞器投产。
在一些实施方式中，所述悬挂卡瓦的内周面上设置有卡瓦牙，所述悬挂卡瓦的外周面形成为从上向下的渐缩面，所述油管悬挂器的上端的内周面形成为从上向下的渐缩面，以容纳并悬挂所述悬挂卡瓦。
在一些实施方式中，所述悬挂卡瓦包括两个半管状部分以及用于可拆卸地连接两个所述半管状部分的连接件。
在一些实施方式中，所述油管悬挂器与所述井口四通密封接合，所述油管悬挂器通过所述井口四通的顶丝固定。
在一些实施方式中，在S3中，所述更换用于完井管柱的入井工具串包括：打开所述操作窗，拆卸用于通洗井的入井工具串，在所述连续管的下端安装丢手、封隔器、堵塞器，并将所述油管悬挂器挂在所述封隔器上。
在一些实施方式中，在S3中，在所述继续下入所述连续管至设计深度之后，对管内打压使得所述封隔器在设计位置坐封，继续下放所述连续管以释放所述注入头的一部分悬重。
在一些实施方式中，所述S3还包括：开启所述泄压三通并通过地面节流管汇控制放喷，将所述封隔器上部压力释放，在环空区域中注满封隔液，使得井口无压力。
在一些实施方式中，在S3中，所述继续下入所述连续管至设计深度包括：以不超过5m/min速度下入所述连续管，当下放深度达到50m时观察设备运转；再以25-30m/min的速度继续下入所述连续管，下放过程中每下放500m进行一次上提悬重测试；下至距设计深度300m时，降低速度至10-15m/min，下至距设计深度100m时，降低速度至5m/min，下过设计深度15m后上提至设计深度。
在一些实施方式中，在S1中，测试所述四闸板防喷器的各闸板开关功能，使其处于全开位置，接着安装所述注入头、所述防喷盒、所述四闸板防喷器、所述泄压三通、所述防喷管、所述操作窗，连接于地面高压泵组管线分别进行地面管线及井口设备试压。
在一些实施方式中，所述试压要求按10％、50％、100％逐级提高泵压至35MPa，以稳压10min、压降小于0.7MPa为合格，如果发现泄漏立即停泵泄压整改。
在一些实施方式中，在S2中，将所述连续管穿过所述注入头，下至所述操作窗位置；打开所述操作窗，对所述连续管的下端进行倒角，安装连接器，并进行拉力测试；在所述连接器 下端安装马达头及通洗井工具，关闭所述操作窗，通过地面高压泵组管线对井口设备试压；打开平板阀，下入所述连续管至设计深度，开启所述地面高压泵组管线，完成对设计区域的通洗井作业。
在一些实施方式中，在安装所述连接器过程中，对所述连续管下端部进行45°倒角处理；对所述连接器进行15吨的拉力测试，其中位移小于3-5mm为合格。
在一些实施方式中，在S4中，打开所述操作窗，将所述悬挂卡瓦安装至所述连续管外壁且靠近所述油管悬挂器上部；继续下入所述连续管，所述悬挂卡瓦落入所述油管悬挂器内，继续下入所述连续管至所述注入头悬重为零且所述连续管无滑移、载荷无异常后，使用所述四闸板防喷器的剪切闸板剪断所述连续管，提升所述连续管并观察所述注入头的载荷与压力变化，验证剪管是否成功。
在一些实施方式中，在S5中，拆除所述井口四通以上所有设备，利用手动割刀割断所述悬挂卡瓦以上的所述连续管，对所述连续管上端管口进行倒角，清除割管缩颈及毛刺。
在一些实施方式中，在所述采气树中安装1号衬管和2号衬管，组装所述采气树，关闭采气树主阀；通过地面高压泵组管线打压打掉堵塞器的堵头后，关井。
通过上述技术方案，通过在剪管前预制悬挂卡瓦，避免了井口设备临时悬挂造成的安全隐患。
附图说明
图1—连续管完井管柱结构示意图
图2—连续管完井管柱工艺井口装置示意图
图3—连续管完井管柱工艺井口流程示意图
图4—连续管通洗井工具串示意图
图5—连续管完井工具串示意图
图6—安装悬挂卡瓦过程示意图
图7—连续管井口悬挂过程示意图
图8—连续管悬挂卡瓦结构图
图9—油管悬挂器结构图
图10—连续管连接器结构图
图11—连续管丢手结构图
图12—连续管封隔器结构图
图13—连续管堵塞器结构图
图14—井口采气树结构图
附图标记说明
1：连续管；2：悬挂卡瓦；2-1：卡瓦牙；2-2：悬挂器外壁；3-油管悬挂器；3-1：悬挂
器主体；3-2：密封总成；4：连接器；4-1：卡瓦连接；4-2：胶筒密封；5：丢手；5-1：上接头；5-2：销钉；5-3：下接头；6：封隔器；6-1：铆钉卡瓦；6-2：环空密封胶筒；7：堵塞器；7-1：双瓣回压阀；7-2：堵头；7-3：筛网，7-4：导引头；8：注入头；9：防喷盒；10：四闸板防喷器；11-防喷管；12：泄压三通；13：操作窗；14：平板阀；15：井口四通；16：马达 头；17：通洗井工具；18：采气树；18-1：1号衬管；18-2：2号衬管。
具体实施方式
以下结合附图对本发明的具体实施方式进行详细说明。应当理解的是，此处所描述的具体实施方式仅用于说明和解释本发明，并不用于限制本发明。
实施例一
本方案提供了一种连续管井口悬挂、井底封堵完井管柱的施工方法，其中，所述施工方法包括：
S1、摆放连续管1作业设备，安装井口设备并试压，其中，所述井口设备从上至下分别为注入头8、防喷盒9、四闸板防喷器10、防喷管11、泄压三通12、操作窗13，参考图2所示；
S2、将连续管1穿过所述注入头8，安装用于通洗井的入井工具串，下管至设计位置，进行通洗井作业；
S3、提升所述连续管1至所述操作窗13，更换用于完井管柱的入井工具串，在所述连续管1上设置油管悬挂器3，下入所述连续管1，使得所述油管悬挂器3落入井口四通15并坐封，继续下入所述连续管1至设计深度；
S4、打开所述操作窗13，在所述连续管1上安装悬挂卡瓦2，下入所述连续管1使得所述悬挂卡瓦2落入所述油管悬挂器3中，继续下入至悬重为零后，割断所述连续管1；
S5、移除井口设备，恢复采气树18，打掉堵塞器7投产。
其中，油管悬挂器3可移动地设置在连续管1上，因此，在下入连续管1时，可以使得油管悬挂器3落到井口四通15上而坐封；参考图6和图7所示，悬挂卡瓦2固定在连续管1上，随着连续管1的向下移动可以持在油管悬挂器3中，从而将连续管1悬挂于油管悬挂器3上，解决了临时悬挂带来的风险。
本方案中，通过在剪管前预制悬挂卡瓦，避免了井口设备临时悬挂造成的安全隐患。
其中，参考图8和图9所示，所述悬挂卡瓦2的内周面上设置有卡瓦牙2-1，所述悬挂卡瓦2的外周面形成为从上向下的渐缩面，所述油管悬挂器3的上端的内周面形成为从上向下的渐缩面，以容纳并悬挂所述悬挂卡瓦2。如图8所示，悬挂卡瓦2通过卡瓦牙2-1与连续管1外壁咬合，外周面与油管悬挂器3内周面相配合，以通过油管悬挂器3来轴向向上支撑悬挂卡瓦2，连续管1通过自重与悬挂卡瓦2相连后，悬挂卡瓦2则通过油管悬挂器3将连续管1悬挂于井口。
如图9所示，所述油管悬挂器3包括悬挂器主体3-1以及密封总成3-2，内周面的密封槽与悬挂卡瓦2外周面相配合。
其中，所述悬挂卡瓦2包括两个半管状部分以及用于可拆卸地连接两个所述半管状部分的连接件。如图8所示，悬挂卡瓦2主要由两个半管状部分组成，并通过连接件可拆卸地连接，通过这样的结构，便于将悬挂卡瓦2安装在连续管1上。
其中，所述油管悬挂器3与所述井口四通15密封接合，所述油管悬挂器3通过所述井口四通15的顶丝固定。参考图14所示，油管悬挂器3设置在井口四通15中，其外周与井口四通15的内周密封接合，实现密封。井口四通15通过径向的顶丝顶紧油管悬挂器3，实现相对 固定。
其中，在S3中，所述更换用于完井管柱的入井工具串包括：打开所述操作窗13，拆卸用于通洗井的入井工具串，在所述连续管1的下端安装丢手5、封隔器6、堵塞器7，并将所述油管悬挂器3挂在所述封隔器6上，参考图5所示。丢手5、封隔器6、堵塞器7为完井工具串，通过操作窗13，拆卸入井工具串后，将完井工具串安装于连续管1的下端。
如图11所示，丢手5采用机械式丢手结构，从上至下包括上接头5-1、销钉5-2以及下接头5-3结构，安装于连接器4与封隔器6之间，连续管1底端工具串遇卡时，通过上提管柱剪断销钉5-2，实现连续管1丢手作业。
如图12所示，封隔器6安装于丢手5与堵塞器7之间，通过管内打压，可以实现在封隔器6位置的连续管1与套管环空通道的封堵。
如图13所示，所述堵塞器7采用功能集成设计，从上至下包括双瓣回压阀7-1、堵头7-2、筛网7-3以及导引头7-4。双瓣回压阀7-1位于堵头7-2前端，由控制滑套约束处于开启状态，通过投球打掉控制滑套，启动双瓣回压阀7-1，实现带压起管。堵头7-2置于堵塞器7末端，实现管内封堵，通过打压剪断固定销钉泵落堵头7-2进行投产。筛网7-3位于堵塞器7功能区下端，采用格栅形设计，网格间距可以根据生产需要进行调整。导引头7-4位于堵塞器7尾端，与筛网7-3相连，通过所述铆钉进行固定。
另外，在S3中，在所述继续下入所述连续管1至设计深度之后，对管内打压使得所述封隔器6在设计位置坐封，继续下放所述连续管1以释放所述注入头8的一部分悬重。当连续管1的下端到达设计深度后，通过向连续管1内打压，使得封隔器6坐封在套管上，进一步地下放连续管1，从而释放注入头8的一部分悬重。封隔器6可以实现连续管作为完井管柱对井下环空的封堵，可以开展特定生产层段的开发。
进一步的，所述S3还包括：开启所述泄压三通12并通过地面节流管汇控制放喷，将所述封隔器6上部压力释放，在环空区域中注满封隔液，使得井口无压力。在环空注入封隔液，起到保护套管及生产管柱和井口不带压安全作业的作用。
其中，在S3中，所述继续下入所述连续管1至设计深度包括：以不超过5m/min速度下入所述连续管1，当下放深度达到50m时观察设备运转；再以25m/min的速度继续下入所述连续管1，下放过程中每下放500m进行一次上提悬重测试；下至距设计深度300m时，降低速度至10m/min，下至距设计深度100m时，降低速度至5m/min，下过设计深度15m后上提至设计深度。在下入所述连续管1时，先以较小的速度下管，再以较大的速度下管，并且进行悬重测试，最后再以较小的速度下管，并且下管深度超过设计深度后再上提。
其中，在S1中，测试所述四闸板防喷器10的各闸板开关功能，使其处于全开位置，接着安装所述注入头8、所述防喷盒9、所述四闸板防喷器10、所述泄压三通12、所述防喷管11、所述操作窗13，连接于地面高压泵组管线分别进行地面管线及井口设备试压。通过地面高压泵组管线(参考图3所示)进行试压，以检测是否存在泄漏。
进一步的，所述试压要求按10％、50％、100％逐级提高泵压至35MPa，以稳压10min、压降小于0.7MPa为合格，如果发现泄漏立即停泵泄压整改。试压时，逐级提高压力，当达到最大压力后，需要保持对应压力一定的时长，如果存在泄漏，需要整改维修。
其中，在S2中，将所述连续管1穿过所述注入头8，下至所述操作窗13位置；打开所 述操作窗13，对所述连续管1的下端进行倒角，安装所述连接器4，并进行拉力测试；参考图4所示，在所述连接器4下端安装马达头16及通洗井工具17，关闭所述操作窗13，通过地面高压泵组管线对井口设备试压；打开所述平板阀14，下入所述连续管1至设计深度，开启所述地面高压泵组管线，完成对设计区域的通洗井作业。如图4所示，在连接器4下端安装马达头16及通洗井工具17。如图10所示，连接器4采用胶筒密封设计，从上至下包括卡瓦连接4-1，及胶筒密封4-2，安装于连续管1底部，使得连续管1可以与井下工具组合相连。
进一步的，在安装所述连接器4过程中，对所述连续管1下端部进行45°倒角处理；对所述连接器4进行15t的拉力测试，其中位移小于3-5mm为合格。对连续管1进行倒角，以便于与连接器4连接；对连接器4进行拉力测试，以确认其连接强度。
其中，在S4中，打开所述操作窗13，将所述悬挂卡瓦2安装至所述连续管1外壁且靠近所述油管悬挂器3上部；继续下入所述连续管1，所述悬挂卡瓦2落入所述油管悬挂器3内，继续下入所述连续管1至所述注入头8悬重为零且所述连续管1无滑移、载荷无异常后，使用所述四闸板防喷器10的剪切闸板剪断所述连续管1，提升所述连续管1并观察所述注入头8的载荷与压力变化，验证剪管是否成功。悬挂卡瓦2安装于连续管1后，下入连续管1，使得悬挂卡瓦2悬挂在油管悬挂器3上，继续下入连续管1，使得连续管1对注入头8的向下的拉力作用为零，剪断连续管1；提升剪断位置以上的连续管1，以判断连续管1是否被剪断。
其中，在S5中，拆除所述井口四通15以上所有设备，利用手动割刀割断所述悬挂卡瓦2以上的所述连续管1，对所述连续管1上端管口进行倒角，清除割管缩颈及毛刺。
其中，在所述采气树18中安装1号衬管和2号衬管，组装所述采气树18，关闭采气树18主阀；通过地面高压泵组管线打压打掉堵塞器7的堵头7-2，关井。参考图14所示，采气树18包括多段结构，在连接多段结构之前，在其中安装1号衬管18-1和2号衬管18-2，使得1号衬管18-1和2号衬管18-2与连续管1对接，然后连接多段结构，关闭采气树18的主阀；地面高压泵组管线打压，以将打掉堵塞器7的堵头7-2，连通储层和连续管1，关井。
实施例二
本方案提供了一种连续管井口悬挂、井底封堵完井管柱的施工方法，其中，所述施工方法包括：
S1、摆放连续管1作业设备，安装井口设备并试压，其中，所述井口设备从上至下分别为注入头8、防喷盒9、四闸板防喷器10、防喷管11、泄压三通12、操作窗13，参考图2所示；
S2、将连续管1穿过所述注入头8，安装用于通洗井的入井工具串，下管至设计位置，进行通洗井作业；
S3、提升所述连续管1至所述操作窗13，更换用于完井管柱的入井工具串，在所述连续管1上设置油管悬挂器3，下入所述连续管1，使得所述油管悬挂器3落入井口四通15并坐封，继续下入所述连续管1至设计深度；
S4、打开所述操作窗13，在所述连续管1上安装悬挂卡瓦2，下入所述连续管1使得所述悬挂卡瓦2落入所述油管悬挂器3中，继续下入至悬重为零后，割断所述连续管1；
S5、移除井口设备，恢复采气树18，打掉堵塞器7投产。
其中，油管悬挂器3可移动地设置在连续管1上，因此，在下入连续管1时，可以使得 油管悬挂器3落到井口四通15上而坐封；参考图6和图7所示，悬挂卡瓦2固定在连续管1上，随着连续管1的向下移动可以持在油管悬挂器3中，从而将连续管1悬挂于油管悬挂器3上，解决了临时悬挂带来的风险。
本方案中，通过在剪管前预制悬挂卡瓦，避免了井口设备临时悬挂造成的安全隐患。
其中，参考图8和图9所示，所述悬挂卡瓦2的内周面上设置有卡瓦牙2-1，所述悬挂卡瓦2的外周面形成为从上向下的渐缩面，所述油管悬挂器3的上端的内周面形成为从上向下的渐缩面，以容纳并悬挂所述悬挂卡瓦2。如图8所示，悬挂卡瓦2通过卡瓦牙2-1与连续管1外壁咬合，外周面与油管悬挂器3内周面相配合，以通过油管悬挂器3来轴向向上支撑悬挂卡瓦2，连续管1通过自重与悬挂卡瓦2相连后，悬挂卡瓦2则通过油管悬挂器3将连续管1悬挂于井口。
如图9所示，所述油管悬挂器3包括悬挂器主体3-1以及密封总成3-2，内周面的密封槽与悬挂卡瓦2外周面相配合。
其中，所述悬挂卡瓦2包括两个半管状部分以及用于可拆卸地连接两个所述半管状部分的连接件。如图8所示，悬挂卡瓦2主要由两个半管状部分组成，并通过连接件可拆卸地连接，通过这样的结构，便于将悬挂卡瓦2安装在连续管1上。
其中，所述油管悬挂器3与所述井口四通15密封接合，所述油管悬挂器3通过所述井口四通15的顶丝固定。参考图14所示，油管悬挂器3设置在井口四通15中，其外周与井口四通15的内周密封接合，实现密封。井口四通15通过径向的顶丝顶紧油管悬挂器3，实现相对固定。
其中，在S3中，所述更换用于完井管柱的入井工具串包括：打开所述操作窗13，拆卸用于通洗井的入井工具串，在所述连续管1的下端安装丢手5、封隔器6、堵塞器7，并将所述油管悬挂器3挂在所述封隔器6上，参考图5所示。丢手5、封隔器6、堵塞器7为完井工具串，通过操作窗13，拆卸入井工具串后，将完井工具串安装于连续管1的下端。
如图11所示，丢手5采用机械式丢手结构，从上至下包括上接头5-1、销钉5-2以及下接头5-3结构，安装于连接器4与封隔器6之间，连续管1底端工具串遇卡时，通过上提管柱剪断销钉5-2，实现连续管1丢手作业。
如图12所示，封隔器6安装于丢手5与堵塞器7之间，通过管内打压，可以实现在封隔器6位置的连续管1与套管环空通道的封堵。
如图13所示，所述堵塞器7采用功能集成设计，从上至下包括双瓣回压阀7-1、堵头7-2、筛网7-3以及导引头7-4。双瓣回压阀7-1位于堵头7-2前端，由控制滑套约束处于开启状态，通过投球打掉控制滑套，启动双瓣回压阀7-1，实现带压起管。堵头7-2置于堵塞器7末端，实现管内封堵，通过打压剪断固定销钉泵落堵头7-2进行投产。筛网7-3位于堵塞器7功能区下端，采用格栅形设计，网格间距可以根据生产需要进行调整。导引头7-4位于堵塞器7尾端，与筛网7-3相连，通过所述铆钉进行固定。
另外，在S3中，在所述继续下入所述连续管1至设计深度之后，对管内打压使得所述封隔器6在设计位置坐封，继续下放所述连续管1以释放所述注入头8的一部分悬重。当连续管1的下端到达设计深度后，通过向连续管1内打压，使得封隔器6坐封在套管上，进一步地下放连续管1，从而释放注入头8的一部分悬重。封隔器6可以实现连续管作为完井管柱对井下 环空的封堵，可以开展特定生产层段的开发。
进一步的，所述S3还包括：开启所述泄压三通12并通过地面节流管汇控制放喷，将所述封隔器6上部压力释放，在环空区域中注满封隔液，使得井口无压力。在环空注入封隔液，起到保护套管及生产管柱和井口不带压安全作业的作用。
其中，在S3中，所述继续下入所述连续管1至设计深度包括：以不超过5m/min速度下入所述连续管1，当下放深度达到50m时观察设备运转；再以30m/min的速度继续下入所述连续管1，下放过程中每下放500m进行一次上提悬重测试；下至距设计深度300m时，降低速度至15m/min，下至距设计深度100m时，降低速度至5m/min，下过设计深度15m后上提至设计深度。在下入所述连续管1时，先以较小的速度下管，再以较大的速度下管，并且进行悬重测试，最后再以较小的速度下管，并且下管深度超过设计深度后再上提。
其中，在S1中，测试所述四闸板防喷器10的各闸板开关功能，使其处于全开位置，接着安装所述注入头8、所述防喷盒9、所述四闸板防喷器10、所述泄压三通12、所述防喷管11、所述操作窗13，连接于地面高压泵组管线分别进行地面管线及井口设备试压。通过地面高压泵组管线进行试压，以检测是否存在泄漏。
进一步的，所述试压要求按10％、50％、100％逐级提高泵压至35MPa，以稳压10min、压降小于0.7MPa为合格，如果发现泄漏立即停泵泄压整改。试压时，逐级提高压力，当达到最大压力后，需要保持对应压力一定的时长，如果存在泄漏，需要整改维修。
其中，在S2中，将所述连续管1穿过所述注入头8，下至所述操作窗13位置；打开所述操作窗13，对所述连续管1的下端进行倒角，安装所述连接器4，并进行拉力测试；参考图4所示，在所述连接器4下端安装马达头16及通洗井工具17，关闭所述操作窗13，通过地面高压泵组管线对井口设备试压；打开所述平板阀14，下入所述连续管1至设计深度，开启所述地面高压泵组管线，完成对设计区域的通洗井作业。如图4所示，在连接器4下端安装马达头16及通洗井工具17。如图10所示，连接器4采用胶筒密封设计，从上至下包括卡瓦连接4-1，及胶筒密封4-2，安装于连续管1底部，使得连续管1可以与井下工具组合相连。
进一步的，在安装所述连接器4过程中，对所述连续管1下端部进行45°倒角处理；对所述连接器4进行15t的拉力测试，其中位移小于3-5mm为合格。对连续管1进行倒角，以便于与连接器4连接；对连接器4进行拉力测试，以确认其连接强度。
其中，在S4中，打开所述操作窗13，将所述悬挂卡瓦2安装至所述连续管1外壁且靠近所述油管悬挂器3上部；继续下入所述连续管1，所述悬挂卡瓦2落入所述油管悬挂器3内，继续下入所述连续管1至所述注入头8悬重为零且所述连续管1无滑移、载荷无异常后，使用所述四闸板防喷器10的剪切闸板剪断所述连续管1，提升所述连续管1并观察所述注入头8的载荷与压力变化，验证剪管是否成功。悬挂卡瓦2安装于连续管1后，下入连续管1，使得悬挂卡瓦2悬挂在油管悬挂器3上，继续下入连续管1，使得连续管1对注入头8的向下的拉力作用为零，剪断连续管1；提升剪断位置以上的连续管1，以判断连续管1是否被剪断。
其中，在S5中，拆除所述井口四通15以上所有设备，利用手动割刀割断所述悬挂卡瓦2以上的所述连续管1，对所述连续管1上端管口进行倒角，清除割管缩颈及毛刺。
其中，在所述采气树18中安装1号衬管和2号衬管，组装所述采气树18，关闭采气树18主阀；通过地面高压泵组管线打压打掉堵塞器7的堵头7-2，关井。参考图14所示，采气 树18包括多段结构，在连接多段结构之前，在其中安装1号衬管18-1和2号衬管18-2，使得1号衬管18-1和2号衬管18-2与连续管1对接，然后连接多段结构，关闭采气树18的主阀；地面高压泵组管线打压，以将打掉堵塞器7的堵头7-2，连通储层和连续管1，关井。
以下说明本方案的优选实施方式的连续管井口悬挂、井底封堵完井管柱的施工方法，包括如下步骤：
第一步：按照油气井用连续管作业推荐作法摆放连续管作业设备，拆卸原井口装置，仅保留平板阀14。测试四闸板防喷器10各闸板开关功能，使其处于全开位置。如图2所示，安装注入头8、防喷盒9、四闸板防喷器10、泄压三通12、防喷管11、操作窗13于平板阀14之上。如图3所示，进行地面管线连接，并对地面高压泵组管线及井口分别试压，试压要求按10％、50％、100％逐级提高泵压至35MPa，稳压10min，压降小于0.7MPa为合格，发现泄漏立即停泵泄压整改。
第二步：将连续管1穿过注入头8，下至操作窗13位置。打开操作窗13，对连续管1下端进行倒角，安装连接器4，安装连接器4过程中连续管1下端部进行45°倒角处理，尽量保证连续管1垂直，避免安装损伤密封圈。安装完毕以后并进行拉力测试，拉力测试15t，位移小于3-5mm为合格。如图4所示，在连接器4下端安装马达头16及通洗井工具17，关闭操作窗13，通过地面高压泵组管线对井口设备试压。打开平板阀14，下管至设计深度，开启地面泵组，完成对设计区域的通洗井作业，保证井筒内壁清洁。
第三步：将连续管1起至操作窗13位置，关闭平板阀14。打开操作窗13，拆下马达头16、通洗井工具17，在连接器4下端安装丢手5、封隔器6、堵塞器7，将油管悬挂器3挂在封隔器6之上，如图5所示，将入井工具串收入防喷管11内。关闭操作窗13，通过地面高压泵组管线对入井工具串试压。打开平板阀14，缓慢下管，油管悬挂器3落入井口四通15内，顶丝固定坐封。连续管1穿过油管悬挂器3继续缓慢下管，下管速度不超过5m/min，下放深度50m时观察设备运转，待设备运转正常后，控制恒定下放速度正常下管，速度控制在25m/min，下放过程中每下放500m进行一次上提悬重测试，下放过程中注意连续管1压力的变化，下至距设计深度300m时，降低速度至10m/min，下至距设计深度100m时，降低速度至5m/min，下过设计深度15m后上提至设计深度。管内打压使得封隔器6在设计位置坐封，继续下放连续管1释放注入头8最大悬重的1/3，确认封隔器6处于正常工作状态，实现环空位置的密封封隔。开启泄压三通12通过地面节流管汇控制放喷，将封隔器6上部压力释放，待压力释放完毕后，注入封隔液，直至环空区域全部注满，井口无压力。
第四步：如图6所示，打开操作窗13，将悬挂卡瓦2安装至连续管1外壁靠近油管悬挂器3上部。如图7所示，下入连续管1，悬挂卡瓦2落入油管悬挂器3内槽，继续下入至注入头8悬重为零且连续管1无滑移，载荷无异常后，使用四闸板防喷器10剪切闸板剪管，起管观察注入头8载荷与压力变化，验证剪管是否成功。
第五步：拆除井口四通15以上所有设备，利用手动割刀割断悬挂卡瓦2以上连续管1，对连续管1上端管口进行倒角，清除割管缩颈及毛刺。采气树18内安装一号衬管18-1和二号衬管18-2，如图14所示，恢复采气井口，关闭采气树18主阀。地面高压泵组管线打压，直至井口压力有突降显示，确定打掉堵塞器7的堵头7-2，关井。
以上结合附图详细描述了本发明的优选实施方式，但是，本发明并不限于此。在本发明的技术构思范围内，可以对本发明的技术方案进行多种简单变型，包括各个具体技术特征以任何合适的方式进行组合。为了避免不必要的重复，本发明对各种可能的组合方式不再另行说明。但这些简单变型和组合同样应当视为本发明所公开的内容，均属于本发明的保护范围。

Claims (15)

  1. 一种连续管井口悬挂、井底封堵完井管柱的施工方法，其特征在于，所述施工方法包括：
    S1、摆放连续管(1)作业设备，安装井口设备并试压，其中，所述井口设备从上至下分别为注入头(8)、防喷盒(9)、四闸板防喷器(10)、防喷管(11)、泄压三通(12)、操作窗(13)；
    S2、将连续管(1)穿过所述注入头(8)，安装用于通洗井的入井工具串，下管至设计位置，进行通洗井作业；
    S3、提升所述连续管(1)至所述操作窗(13)，更换用于完井管柱的入井工具串，在所述连续管(1)上设置油管悬挂器(3)，下入所述连续管(1)，使得所述油管悬挂器(3)落入井口四通(15)并坐封，继续下入所述连续管(1)至设计深度；
    S4、打开所述操作窗(13)，在所述连续管(1)上安装悬挂卡瓦(2)，下入所述连续管(1)使得所述悬挂卡瓦(2)落入所述油管悬挂器(3)中，继续下入至悬重为零后，割断所述连续管(1)；
    S5、移除井口设备，恢复采气树(18)，打通堵塞器(7)投产。
  2. 根据权利要求1所述的连续管井口悬挂、井底封堵完井管柱的施工方法，其特征在于，所述悬挂卡瓦(2)的内周面上设置有卡瓦牙(2-1)，所述悬挂卡瓦(2)的外周面形成为从上向下的渐缩面，所述油管悬挂器(3)的上端的内周面形成为从上向下的渐缩面，以容纳并悬挂所述悬挂卡瓦(2)。
  3. 根据权利要求2所述的连续管井口悬挂、井底封堵完井管柱的施工方法，其特征在于，所述悬挂卡瓦(2)包括两个半管状部分以及用于可拆卸地连接两个所述半管状部分的连接件。
  4. 根据权利要求2所述的连续管井口悬挂、井底封堵完井管柱的施工方法，其特征在于，所述油管悬挂器(3)与所述井口四通(15)密封接合，所述油管悬挂器(3)通过所述井口四通(15)的顶丝固定。
  5. 根据权利要求2所述的连续管井口悬挂、井底封堵完井管柱的施工方法，其特征在于，在S3中，所述更换用于完井管柱的入井工具串包括：打开所述操作窗(13)，拆卸用于通洗井的入井工具串，在所述连续管(1)的下端安装丢手(5)、封隔器(6)、堵塞器(7)，并将所述油管悬挂器(3)挂在所述封隔器(6)上。
  6. 根据权利要求5所述的连续管井口悬挂、井底封堵完井管柱的施工方法，其特征在于，在S3中，在所述继续下入所述连续管(1)至设计深度之后，对管内打压使得所述封隔器(6)在设计位置坐封，继续下放所述连续管(1)以释放所述注入头(8)的一部分悬重。
  7. 根据权利要求6所述的连续管井口悬挂、井底封堵完井管柱的施工方法，其特征在于，所述S3还包括：开启所述泄压三通(12)并通过地面节流管汇控制放喷，将所述封隔器(6)上部压力释放，在环空区域中注满封隔液，使得井口无压力。
  8. 根据权利要求2所述的连续管井口悬挂、井底封堵完井管柱的施工方法，其特征在于，在S3中，所述继续下入所述连续管(1)至设计深度包括：以不超过5m/min速度下入所述连续管(1)，当下放深度达到50m时观察设备运转；再以25-30m/min的速度继续下入所述连 续管(1)，下放过程中每下放500m进行一次上提悬重测试；下至距设计深度300m时，降低速度至10-15m/min，下至距设计深度100m时，降低速度至5m/min，下过设计深度15m后上提至设计深度。
  9. 根据权利要求2所述的连续管井口悬挂、井底封堵完井管柱的施工方法，其特征在于，在S1中，测试所述四闸板防喷器(10)的各闸板开关功能，使其处于全开位置，接着安装所述注入头(8)、所述防喷盒(9)、所述四闸板防喷器(10)、所述泄压三通(12)、所述防喷管(11)、所述操作窗(13)，连接于地面高压泵组管线分别进行地面管线及井口设备试压。
  10. 根据权利要求9所述的连续管井口悬挂、井底封堵完井管柱的施工方法，其特征在于，所述试压要求按10％、50％、100％逐级提高泵压至35MPa，以稳压10min、压降小于0.7MPa为合格，如果发现泄漏立即停泵泄压整改。
  11. 根据权利要求1所述的连续管井口悬挂、井底封堵完井管柱的施工方法，其特征在于，在S2中，将所述连续管(1)穿过所述注入头(8)，下至所述操作窗(13)位置；打开所述操作窗(13)，对所述连续管(1)的下端进行倒角，安装连接器(4)，并进行拉力测试；在所述连接器(4)下端安装马达头(16)及通洗井工具(17)，关闭所述操作窗(13)，通过地面高压泵组管线对井口设备试压；打开平板阀(14)，下入所述连续管(1)至设计深度，开启所述地面高压泵组管线，完成对设计区域的通洗井作业。
  12. 根据权利要求11所述的连续管井口悬挂、井底封堵完井管柱的施工方法，其特征在于，在安装所述连接器(4)过程中，对所述连续管(1)下端部进行45°倒角处理；对所述连接器(4)进行15吨的拉力测试，其中位移小于3-5mm为合格。
  13. 根据权利要求1所述的连续管井口悬挂、井底封堵完井管柱的施工方法，其特征在于，在S4中，打开所述操作窗(13)，将所述悬挂卡瓦(2)安装至所述连续管(1)外壁且靠近所述油管悬挂器(3)上部；继续下入所述连续管(1)，所述悬挂卡瓦(2)落入所述油管悬挂器(3)内，继续下入所述连续管(1)至所述注入头(8)悬重为零且所述连续管(1)无滑移、载荷无异常后，使用所述四闸板防喷器(10)的剪切闸板剪断所述连续管(1)，提升所述连续管(1)并观察所述注入头(8)的载荷与压力变化，验证剪管是否成功。
  14. 根据权利要求1所述的连续管井口悬挂、井底封堵完井管柱的施工方法，其特征在于，在S5中，拆除所述井口四通(15)以上所有设备，利用手动割刀割断所述悬挂卡瓦(2)以上的所述连续管(1)，对所述连续管(1)上端管口进行倒角，清除割管缩颈及毛刺。
  15. 根据权利要求14所述的连续管井口悬挂、井底封堵完井管柱的施工方法，其特征在于，在所述采气树(18)中安装1号衬管(18-1)和2号衬管(18-2)，组装所述采气树(18)，关闭采气树(18)主阀；通过地面高压泵组管线打压打掉堵塞器(7)的堵头(7-2)后，关井。
PCT/CN2023/136160 2023-06-01 2023-12-04 连续管井口悬挂、井底封堵完井管柱的施工方法 Ceased WO2024244359A1 (zh)

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