CN113803019B - Well completion method and string for horizontal well - Google Patents
Well completion method and string for horizontal well Download PDFInfo
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- CN113803019B CN113803019B CN202010544381.5A CN202010544381A CN113803019B CN 113803019 B CN113803019 B CN 113803019B CN 202010544381 A CN202010544381 A CN 202010544381A CN 113803019 B CN113803019 B CN 113803019B
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- 238000000034 method Methods 0.000 title claims abstract description 27
- 239000004568 cement Substances 0.000 claims abstract description 23
- 239000002002 slurry Substances 0.000 claims abstract description 20
- 210000002445 nipple Anatomy 0.000 claims description 27
- 230000015572 biosynthetic process Effects 0.000 claims description 14
- 210000000078 claw Anatomy 0.000 claims description 7
- 230000007704 transition Effects 0.000 claims description 5
- 230000009471 action Effects 0.000 claims description 4
- 238000002347 injection Methods 0.000 claims description 3
- 239000007924 injection Substances 0.000 claims description 3
- 230000002512 anti-withdrawal effect Effects 0.000 claims 1
- 230000009286 beneficial effect Effects 0.000 abstract description 3
- 238000005755 formation reaction Methods 0.000 description 10
- 230000008569 process Effects 0.000 description 6
- 238000002955 isolation Methods 0.000 description 5
- 238000010008 shearing Methods 0.000 description 5
- 238000007789 sealing Methods 0.000 description 4
- 238000010276 construction Methods 0.000 description 3
- 238000012856 packing Methods 0.000 description 3
- 230000002265 prevention Effects 0.000 description 3
- 230000009466 transformation Effects 0.000 description 3
- 230000006835 compression Effects 0.000 description 2
- 238000007906 compression Methods 0.000 description 2
- 238000010586 diagram Methods 0.000 description 2
- 239000012530 fluid Substances 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- 229910000831 Steel Inorganic materials 0.000 description 1
- 230000000994 depressogenic effect Effects 0.000 description 1
- 238000006073 displacement reaction Methods 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000007667 floating Methods 0.000 description 1
- 230000010354 integration Effects 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 230000013011 mating Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 230000000149 penetrating effect Effects 0.000 description 1
- 230000000750 progressive effect Effects 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 239000010959 steel Substances 0.000 description 1
- 238000012546 transfer Methods 0.000 description 1
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Classifications
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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
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
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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
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/06—Valve arrangements for boreholes or wells in wells
- E21B34/063—Valve or closure with destructible element, e.g. frangible disc
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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)
- Consolidation Of Soil By Introduction Of Solidifying Substances Into Soil (AREA)
- Earth Drilling (AREA)
Abstract
The invention relates to a well completion method and a string for a horizontal well. The method comprises the following steps: and (3) lowering a string containing a cementing device into the horizontal well, so that the cementing device is positioned near a weak stratum of a horizontal well section of the horizontal well, and opening a cementing channel of the cementing device, which is communicated with an annulus, so as to inject cement slurry into the annulus between the weak stratum and the string. The method can effectively ensure exploitation of oil and gas wells, and is particularly beneficial to collection of tight oil and gas reservoirs and shale gas.
Description
Technical Field
The invention relates to the technical field of horizontal well completion fixation and completion integration, in particular to a completion fixation and completion method for a horizontal well. The invention also relates to a string for use in a well completion.
Background
Currently, in order to improve the yield and the exploitation efficiency of a tight oil and gas reservoir and a shale gas single well, various reservoir transformation technologies are generally adopted to establish a large drainage channel in a shaft so as to perform a yield increase measure. However, in the case of complex reservoirs such as high-pressure water layers, leakage layers or multi-pressure system reservoirs and the like near the top of the horizontal well section, if large-displacement fracturing and seam-making reservoir reconstruction construction operation is carried out, the water layers, the leakage layers or other pressure system reservoirs are easily communicated. The problems of well shaft flooding, oil gas entering into a leakage layer or damage to a production pressure system and the like can be caused, so that the production efficiency of an oil gas well is greatly reduced.
In the prior art, cementing is generally performed by filling cement slurry in the whole well bore annulus so as to avoid the occurrence of the situation. However, the cost of such an operation is high. In particular, wellbores used to produce tight reservoirs and shale gas are typically deep or ultra-deep wells and are prone to weak formations. If cement slurry is filled throughout the borehole annulus, the time and material costs expended will be very high. This high cost severely hampers current recovery of tight reservoirs and shale gas.
Thus, there is a need for a method that can effectively open oil and gas wells, particularly tight reservoirs and shale gas.
Disclosure of Invention
Aiming at the problems, the invention provides a well completion method for a horizontal well, which can effectively ensure the exploitation of an oil-gas well and is very beneficial to the collection of a compact oil-gas reservoir and shale gas. The invention also provides a pipe string for the well completion of the horizontal well for realizing the method.
According to a first aspect of the present invention, a method for completion of a horizontal well is presented, comprising the steps of: and (3) lowering a string containing a cementing device into the horizontal well, so that the cementing device is positioned near a weak stratum of a horizontal well section of the horizontal well, and opening a cementing channel of the cementing device, which is communicated with an annulus, so as to inject cement slurry into the annulus between the weak stratum and the string.
By the method, the support can be effectively formed at the weak stratum of the horizontal well section only, so that the problems of leakage and the like of the stratum in the subsequent operation process are avoided. The cost of this method is much less than the prior art method of cementing the entire wellbore with cement slurry. Thereby, it is advantageous to ensure the exploitation of oil and gas wells. Especially for the collection of compact oil and gas reservoirs and shale gas, the method can ensure the safe and effective exploitation and greatly reduce the operation cost.
In one embodiment, the string includes an open hole packer below the cementing tool, the open hole packer being set within the horizontal well section after the string is run into the horizontal well and prior to injecting cement slurry through the cementing tool into the annulus.
In one embodiment, the cementing passageway is closed after injecting cement slurry through the cementing tool into the annulus.
In one embodiment, the string further comprises a running tool, the cementing passageway being closed by lifting the running tool.
According to a second aspect of the present invention there is provided a string for completion of a horizontal well comprising a cementing tool located adjacent to a weak formation of a horizontal well section of the horizontal well when the string is run into the horizontal well, the cementing tool comprising an outer barrel and an inner barrel nested within the outer barrel, a cementing passage extending radially through the outer barrel being configured on a side wall of the outer barrel, in a first condition the inner barrel overlapping the cementing passage to close the cementing passage, and in a second condition the inner barrel being offset from the cementing passage to open the cementing passage to allow injection of cement slurry through the cementing passage to an annulus between the weak formation and the string.
In one embodiment, at least a portion of the inner barrel moves in an axially downward direction to transition from the first state to the second state, and/or at least a portion of the inner barrel moves in an axially upward direction to transition from the second state to the first state.
In one embodiment, the cementing device further comprises an overshot sleeved inside the inner barrel and a cementing ball seat sleeved inside the overshot, the string further comprises a fishing device, the overshot is configured to allow a resilient claw of the fishing device to be inserted therein and engaged therewith, in an initial state, the outer barrel and the inner barrel of the cementing device are connected together by a first shear pin to fix the outer barrel and the inner barrel relative to each other, the first shear pin shearing to allow the inner barrel to move in an axial direction relative to the outer barrel when the cementing ball seat is engaged with a cementing ball thrown from a wellhead to thereby transition from a first state to a second state, in an initial state, the inner barrel and the overshot are connected together by a second shear pin, in an initial state, the second shear pin shearing to allow the overshot and the cementing ball seat to be retrieved to the wellhead together with the fishing device.
In one embodiment, the inner barrel comprises a first inner barrel part, a second inner barrel part and a third inner barrel part which are sequentially connected from top to bottom, the third inner barrel part is connected with the outer barrel through a withdrawal prevention clamp spring so as to prevent the inner barrel from moving upwards in a second state to close the cementing channel, in an initial state, the second inner barrel part and the third inner barrel part are connected through a third shearing pin, when the fishing device is lifted, the second inner barrel part moves upwards relative to the third inner barrel part under the action of the withdrawal prevention clamp spring to shear the third shearing pin, the first inner barrel part and the second inner barrel part move upwards axially to be converted into a first state from a second state, and the fishing device is lifted further so that the second shearing pin is sheared to allow the overshot and the cementing ball seat to be recovered to a wellhead together with the fishing device.
In one embodiment, the string further comprises a plurality of open hole packers disposed below the cementing tool, the plurality of open hole packers being arranged spaced apart from one another in an axial direction, the plurality of open hole packers being set within the horizontal well section after the string is run into the horizontal well and before cement slurry is injected into the annulus through the cementing tool.
In one embodiment, the string further comprises a bump-press nipple connected above the fishing device and a telescopic nipple connected above the fishing device, a liner connected to the running tool being connected above the telescopic nipple, the telescopic nipple being configured to allow adjustment of the distance between the liner and the cementing device to enable the fishing device to be compressed in cooperation with the cementing device.
Compared with the prior art, the invention has the advantages that: through the method and the pipe string, the support can be effectively formed only at the weak stratum of the horizontal well section, so that the problems of leakage and the like of the stratum in the subsequent operation process are avoided. The cost of this method is much less than the prior art method of cementing the entire wellbore with cement slurry. Thereby, it is advantageous to ensure the exploitation of oil and gas wells. Especially for the collection of compact oil and gas reservoirs and shale gas, the method can ensure the safe and effective exploitation and greatly reduce the operation cost. In addition, cement slurry is injected into the annular space above the open hole packer, so that the annular space on the upper side and the lower side of the cement slurry can be effectively sealed. Therefore, even if the annular space on the lower side, provided with the open hole packer, has the problems of packing failure, leakage and the like, the annular space on the upper side, which is communicated with the wellhead, is not affected, and high-pressure fluid is not communicated with the wellhead. This is very beneficial for ensuring job safety.
Drawings
The invention is described in more detail hereinafter with reference to the accompanying drawings. Wherein:
FIG. 1 shows a schematic diagram of a string of pipes according to one embodiment of the invention;
FIG. 2 shows a schematic view of a portion of the string of tubes of FIG. 1;
FIG. 3 shows a schematic view of a portion of the string of tubes of FIG. 1;
FIG. 4 shows a schematic view of a portion of the string of tubes of FIG. 1;
fig. 5 shows a schematic view of a portion of the string of pipes of fig. 1.
In the drawings, like parts are designated with like reference numerals. The figures are not drawn to scale.
Detailed Description
The invention will be further described with reference to the accompanying drawings.
One embodiment of a pipe string 100 according to the present invention is shown in fig. 1. In the direction from top to bottom, the string 100 includes a running tool 2, a liner hanger 3, a pressure transmitting tube 4, a sealing joint 5, a rotary nipple 6, a liner 7, a telescopic nipple 8, a bump-press nipple 9, a fishing device 10, a cementing device 11, open hole packers 13 and 14, a ball throwing slide sleeve 15, open hole packers 16 and 17, a ball throwing slide sleeve 18, open hole packers 19 and 20, a differential pressure slide sleeve 21, a downhole isolation valve 23, and a float shoe 24, which are sequentially arranged. The rotary nipple 6, the liner 7, the telescopic nipple 8, the bump-press nipple 9 and the fishing device 10 are inserted into a tail pipe comprising the cementing device 11, the open hole packers 13 and 14, the ball throwing sliding sleeve 15, the open hole packers 16 and 17, the ball throwing sliding sleeve 18, the open hole packers 19 and 20, the differential pressure sliding sleeve 21, the downhole isolation valve 23 and the floating shoe 24.
The running tool 2, liner hanger 3, pressure transfer cylinder 4, sealing joint 6, liner 7, each open hole packer, ball throwing sleeve, differential pressure sleeve 21, downhole isolation valve 23 and buoyancy shoes are all known in the art and are not described in detail herein.
As shown in fig. 2, the cementing device 11 includes an outer barrel 113. The upper end of the outer cylinder 113 is inserted by the upper joint 111 and connected to the upper joint 111. The lower end of the outer cylinder 113 is inserted by the lower joint 112 and connected to the lower joint 112. An inner tube is sleeved in the outer tube 113. In the embodiment shown in fig. 1, the inner barrel includes a first inner barrel 114, a second inner barrel 115, and a third inner barrel 116 that are connected in order from top to bottom. The first inner tube 114 and the second inner tube 115 are screwed together, and a limit clip 203 is provided inside the connecting portion between the first inner tube 114 and the second inner tube 115. The second inner cylinder 115 and the third inner cylinder 116 are connected to each other by a third shear pin 205. The first inner cylinder 114 is connected to the outer cylinder 113 by a first shear pin 202.
It should be appreciated that the inner barrel may be integrally designed, or have other split designs, as desired.
The inner cylinder is restrained between the upper joint 111 and the lower joint 112 in the axial direction. A switch cover 201 is formed on the outer side of the upper end of the inner tube (first inner tube portion 114). The switch sleeve 201 is configured, for example, as a double-sided saw-tooth snap spring for engagement with a corresponding engagement portion (e.g., a thread) inside the lower end of the upper joint 111. Hereinafter, this will be described in more detail in connection with the working process.
Further, a withdrawal prevention clip spring 206 is provided outside the third inner tube portion 116. The anti-back-out snap spring 206 is engaged with the outer cylinder 113 such that the third inner cylinder portion 116 is movable axially downward with respect to the outer cylinder 113, but is not movable axially upward.
The cementing device 111 further includes an overshot 117 disposed in the inner cylinder, and a cementing ball seat 118 disposed in the overshot 117. The overshot 117 is connected to the second inner barrel 115 by a second shear pin 204. The cementing ball seat 118 is threadably connected to the overshot 117. The overshot 117 is configured and adapted to engage the resilient pawl 103 of the fishing apparatus 10 to facilitate the fishing operation.
The limit clamp spring 203 described above is provided on the one hand inside the connecting portion of the first inner cylinder 114 and the second inner cylinder 115, and on the other hand outside the overshot 117. The inner part of the upper end surface of the limit clamp spring 203, which is a plane extending perpendicular to the axial direction, is engaged with the downward facing step surface of the overshot 117. An outer portion of an upper end surface of the limit clip 203, which is an inclined surface inclined radially outward in an axially downward direction, is engaged with a lower end surface of the first inner cylinder portion 114. The outer portion of the lower end surface of the limit clip 203, which is a plane extending perpendicular to the axial direction, is engaged with the stepped surface of the second inner tube 115 facing upward. This configuration allows the limit clamp spring 203 to bear when the string 100 is running down, ensuring that the overshot 117 is fixed relative to the inner barrel. When the overshot 117 is lifted for fishing, the limit clamp spring 203 can be further matched with the first inner cylinder 114 to shrink inwards in the radial direction. At this time, the limit clamp spring 203 no longer plays a role in fixing the overshot 117 with the inner cylinder, and does not interfere with the salvaging operation of the overshot 117.
As shown in fig. 2, a cementing passage 113A penetrating in the radial direction is formed in the side wall of the outer tube 113. In the first state, the inner tube (first inner tube portion 114) overlaps the cementing passageway 113A to close the cementing passageway 113A. In the second state, the inner tube (first inner tube portion 114) is offset from the cementing passage 113A, allowing the cementing passage 113A to open, thereby allowing cement slurry in the cementing machine 111 to flow out of the outer tube 113 of the cementing machine 11 through the cementing passage 113A.
Fig. 2 shows an initial state of the cementing apparatus 111. At this time, each shear pin maintains a position between the inner barrel, outer barrel, and overshot, and closes (i.e., is in a first state) the cementing channel 113A.
Fig. 3 shows a schematic structural diagram of the sequential connection of the telescopic nipple 8, the bump-press nipple 9 and the fishing device 10. As shown in fig. 4, the fishing apparatus 10 includes a fishing joint 101, and a resilient claw 102 connected below the fishing joint 101. A supporting sleeve 103 is sleeved on the inner side of the elastic claw 102. The resilient claw 102 is insertable into the overshot 117 to operate the cementing machine 111. The axial distance between the liner 7 and the cementing device 11 is advantageously adjusted by the telescopic nipple 8. For example, in the case of pressure holding by the pressure-holding nipple 9, the pressure-holding nipple 9 and the fishing device 10 below the telescopic nipple 8 can move downward to facilitate the cooperation and compression of the elastic claw 102 of the fishing device 10 and the overshot 117 of the cementing device 11. An effective connection between the fishing apparatus 10 and the overshot 117 can be achieved by a mating compression between the resilient jaw 102 and the overshot 117. This is very advantageous for improving the fishing efficiency and the fishing success rate of the overshot 117 and its accessories.
Fig. 5 shows a schematic structural view of the rotary nipple 6. The rotary nipple 6 comprises a bearing sleeve 62, a rotary upper joint 61 and a rotary lower joint 65. The lower end of the rotary upper joint 61 is held in the carrier sleeve 62, sealed with the carrier sleeve 62 by a seal 64, and rotationally engaged with the carrier sleeve 62 by a steel ball 63. The upper end of the rotary upper joint 61 extends in an axially upward direction beyond the carrier sleeve 62 and is connected to the sealing joint 5. The upper end of the rotary lower joint 65 is inserted into the carrier sleeve 62 and is located below the rotary upper joint 62. The upper end of the rotary lower joint 65 is fixedly connected with the bearing sleeve 62 and is sealed by a sealing member 66. The lower end of the swivel lower joint 65 extends in an axially downward direction beyond the carrier sleeve 62 and is connected to the bushing. The cooperation between the liner 7 and the outer liner is facilitated by rotating the nipple 6.
An embodiment of the operation of the completion string 100 of the present invention, and thus the completion method of the present invention, will be described in detail below with reference to FIGS. 1-5.
First, the string 100 as described above is lowered into the horizontal well such that the cement mixer 11 is located near the weak formation at the top of the horizontal well section. Preferably, the cementing tool 11 is located in place below the weak formation, i.e., closer to the bottom of the well than the weak formation. For example, if the weak formation is located downhole at a depth of 2000m, the cementing tool may be located downhole at a depth of 2200 m.
Then, the pump is cycled on and a ball is thrown into the string 100 so that the ball mates with the ball seat of the downhole isolation valve 23, thereby realizing pressure build-up in the string 100 to close the downhole isolation valve 23.
Then, the pressure build-up in the string 100 is further performed to seat the liner hanger 3 against the well wall and to seat the open hole packers 13, 14, 16, 17, 19, 20 in the horizontal well section. The open hole packers 13, 14, 16, 17, 19 and 20 can be used for sectionally packing the stratum corresponding to the horizontal well section on one hand and can also play a certain role in supporting the stratum on the other hand.
Thereafter, the string 100 may be depressed a tonnage to verify the setting reliability of the liner hanger 3.
The pressure differential sliding sleeve 21 may then be opened by continuing to hold pressure to again establish a circulation in the well.
The liner hanger 3 may then be run on release so that the liner remains in the well.
Thereafter, the cementing ball 12 may be inserted into the string 100 until it engages with the cementing ball seat 118 of the cementing tool 11, and the pressure is again held. By the pressure holding, the first shear pin 202 connecting the outer tube 113 and the first inner tube 114 is sheared, and the first inner tube 114, the second inner tube 115, the third inner tube 116, the overshot 117, the cementing ball seat 118, and the cementing ball 12 are moved downward together in the axial direction until the cementing passage 113A is opened (second state). Thus, cement slurry may be injected into the annulus between the string 100 and the weak formation. Since the cement mixer 11 is initially positioned a distance below the weak formation, the cement slurry injected into the annulus through the cement mixer 11 is effective to seal the weak formation.
After the cement slurry injection is finished, the drill rod rubber plug 1 is put into the pipe string 100, and the slurry replacement operation is carried out until the drill rod rubber plug 1 is bumped and pressed at the bump and press nipple 9. Continuing to hold pressure, the elastic claw 102 of the fishing device 10 can be in press fit with the overshot 117 of the cementing device 11 under the action of the telescopic pup joint 8. And continuing to build pressure again, opening a channel at the side wall of the collision pressure nipple 9, and reestablishing the underground circulation.
Then, the fishing device 10, the overshot 117 of the cementing tool 11, the cementing ball seat 118, the first inner cylinder 114 and the second inner cylinder 115 are moved upward together by lifting up the drill 2 until the first inner cylinder 114 covers the cementing passageway 113A again to close the cementing passageway 113A (first state). In this process, the third inner cylinder 116 does not move upward with the second inner cylinder 115 due to the action of the anti-back-out snap spring 206 outside the third inner cylinder 116, but maintains its relative position with the outer cylinder 113. Therefore, the third shear pin 205 connecting the second inner tube 115 and the third inner tube 116 is sheared. Here, the first inner cylindrical portion 114 preferably moves upward to a position slightly higher than the initial position so that the upper end thereof is inserted into the lower end of the upper joint 111. Thereby, the switch cover 201 outside the upper end of the first inner tube 114 can be engaged with the engagement portion inside the lower end of the upper joint 111, so that the first inner tube 114 is prevented from descending again to open the cementing passage 113A. It should be understood that in the initial state where the cementing has not been performed, the upper end of the first inner cylinder 114 is not inserted into the lower end of the upper joint 111, so that the switch housing 201 on the first inner cylinder 114 is prevented from being engaged with the engaging portion of the upper joint 111.
Thereafter, the lifting up of the drilling tool 2 is continued to lift the liner 7, the telescopic nipple 8, the bump-in nipple 9, the fishing device 10 and the overshot 117 of the cementing tool 11 together with the cementing ball seat 118 and the cementing ball 12 into the well. In this process, the first inner barrel 114 and the second inner barrel 115 are not lifted out with the overshot 117 due to being blocked by the upper joint 111. The limit clamp spring 203 is retracted inward and no longer engages the first inner barrel 114. Therefore, the second shear pin 204 connecting the second inner cylinder 115 and the overshot 117 shears.
Thereby, the portion left in the tube string 100 can be made to have an inner full diameter.
And after the cement paste is solidified, tail pipe tieback operation can be performed.
In the working process, the differential pressure sliding sleeve 21 is opened, so that the 1 st stage fracturing construction operation can be directly performed.
After the stage 1 fracturing construction operation is completed, the ball-throwing sliding sleeves 18 and 15 can be sequentially opened from bottom to top to perform fracturing operation on the corresponding stratum stages.
Through the pipe string 100 and the method, for example, a horizontal tight oil and gas reservoir and a shale gas well reservoir can be reformed, so that a weak stratum at the top of a horizontal well section can be strengthened and sealed, and the problems of flooding, easy leakage and the like at the weak stratum are avoided. In addition, the reservoir of the horizontal well section can be subjected to segmented progressive fracturing transformation in sequence, the reservoir transformation effect is enhanced, and the oil gas exploitation efficiency is improved. Furthermore, it should be appreciated that the actual size of the wellbore may vary from the designed size, and thus open hole packers may suffer from packing failure or support failure. In this case, the annulus sealed by the cementing device 11 effectively isolates the annulus on its lower side, provided with open hole packers, from the annulus on its upper side, leading to the wellhead. Thus, problems that may occur at open hole packers do not affect the wellhead. For example, high temperature and pressure fluids do not flow to the wellhead via the annulus and affect the safety of the operation.
In this context, the terms "upper" and "lower" refer to a direction extending along the axial direction of the string, where "upper" refers to a direction along the axial direction of the string toward the wellhead, and "lower" refers to a direction along the axial direction of the string toward the bottom of the well, if not otherwise explicitly defined.
While the invention has been described with reference to a preferred embodiment, various modifications may be made and equivalents may be substituted for elements thereof without departing from the scope of the invention. In particular, the technical features mentioned in the respective embodiments may be combined in any manner as long as there is no structural conflict. The present invention is not limited to the specific embodiments disclosed herein, but encompasses all technical solutions falling within the scope of the claims.
Claims (7)
1. A string for well completion of a horizontal well, comprising a cementing tool located adjacent to a weak formation of a horizontal well section of the horizontal well when the string is lowered into the horizontal well, the cementing tool comprising an outer barrel and an inner barrel nested within the outer barrel, a cementing passage extending through the outer barrel in a radial direction being formed in a side wall of the outer barrel, in a first state the inner barrel covering the cementing passage to close the cementing passage, and in a second state the inner barrel being staggered from the cementing passage to open the cementing passage, allowing injection of cement slurry through the cementing passage into an annulus between the weak formation and the string.
2. A pipe string according to claim 1, wherein at least a portion of the inner barrel is moved in an axially downward direction to transition from the first state to the second state and/or at least a portion of the inner barrel is moved in an axially upward direction to transition from the second state to the first state.
3. The pipe string according to claim 1 or 2, wherein the cementing device further comprises an overshot sleeved inside the inner barrel and a cementing ball seat sleeved inside the overshot,
the string further includes a fishing device, the overshot being configured to allow a resilient claw of the fishing device to be inserted therein and engaged therewith,
in an initial state, the outer cylinder and the inner cylinder of the cementing device are connected together through a first shear pin so as to fix the outer cylinder and the inner cylinder relative to each other, when the cementing ball seat is jointed with a cementing ball input from a wellhead to perform pressure holding, the first shear pin is sheared to allow the inner cylinder to move along the axial direction relative to the outer cylinder, thereby being capable of being converted from a first state to a second state,
in an initial state, the inner barrel and the overshot are connected together by a second shear pin, which shears when the fishing device is lifted up, to allow the overshot and the cementing ball seat to be retrieved to the wellhead together with the fishing device.
4. A pipe string according to claim 3, wherein the inner barrel comprises a first inner barrel part, a second inner barrel part and a third inner barrel part which are sequentially connected from top to bottom, the third inner barrel part is connected with the outer barrel through a withdrawal-preventing clamp spring so as to prevent the inner barrel from moving upwards in a second state to seal the cementing channel,
in the initial state, the second inner cylinder part and the third inner cylinder part are connected through a third shear pin,
when the fishing device is lifted, under the action of the anti-withdrawal clamp spring, the second inner cylinder moves upwards relative to the third inner cylinder to shear the third shear pin, the first inner cylinder and the second inner cylinder move upwards axially to be converted into a first state from a second state, and the fishing device is lifted further, so that the second shear pin is sheared, and the fishing cylinder and the cementing ball seat are allowed to be recovered to a wellhead together with the fishing device.
5. A string according to claim 1 or 2, further comprising a plurality of open hole packers disposed below the cementing tool, the plurality of open hole packers being arranged spaced apart from each other in an axial direction, the plurality of open hole packers being set within the horizontal well section after the string is run into the horizontal well and before cement slurry is injected into the annulus through the cementing tool.
6. A string according to claim 5, further comprising a bump-in nipple connected above the fishing device and a telescopic nipple connected above the fishing device, the telescopic nipple being connected above a liner connected to a running tool, the telescopic nipple being configured to allow adjustment of the distance between the liner and the cementing device to enable the fishing device to be compressed in cooperation with the cementing device.
7. A method of completing a horizontal well comprising the steps of:
running a string of pipes according to any one of claims 1 to 6 into the horizontal well such that the cementing tool is located in the vicinity of a weak formation of a horizontal leg of the horizontal well,
a cementing passageway of the cementing tool to the annulus is opened to inject cement slurry into the annulus between the weak formation and the string.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202010544381.5A CN113803019B (en) | 2020-06-15 | 2020-06-15 | Well completion method and string for horizontal well |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202010544381.5A CN113803019B (en) | 2020-06-15 | 2020-06-15 | Well completion method and string for horizontal well |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN113803019A CN113803019A (en) | 2021-12-17 |
| CN113803019B true CN113803019B (en) | 2023-04-25 |
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| CN202010544381.5A Active CN113803019B (en) | 2020-06-15 | 2020-06-15 | Well completion method and string for horizontal well |
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| CN (1) | CN113803019B (en) |
Citations (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| RU2171359C1 (en) * | 2000-03-17 | 2001-07-27 | Открытое Акционерное Общество Акционерная нефтяная компания "Башнефть" | Method of horizontal well completion |
| CN101280674A (en) * | 2008-05-23 | 2008-10-08 | 安东石油技术（集团）有限公司 | Oil well cementing system with inverse squeezing and pouring functions |
| CN101532375A (en) * | 2009-04-13 | 2009-09-16 | 中国石油化工股份有限公司胜利油田分公司采油工艺研究院 | Method for recycling for failure of stage cementing unit and sealed circulation device |
| CN109707335A (en) * | 2017-10-25 | 2019-05-03 | 中国石油化工股份有限公司 | Completion tubular column and completion method |
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2020
- 2020-06-15 CN CN202010544381.5A patent/CN113803019B/en active Active
Patent Citations (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| RU2171359C1 (en) * | 2000-03-17 | 2001-07-27 | Открытое Акционерное Общество Акционерная нефтяная компания "Башнефть" | Method of horizontal well completion |
| CN101280674A (en) * | 2008-05-23 | 2008-10-08 | 安东石油技术（集团）有限公司 | Oil well cementing system with inverse squeezing and pouring functions |
| CN101532375A (en) * | 2009-04-13 | 2009-09-16 | 中国石油化工股份有限公司胜利油田分公司采油工艺研究院 | Method for recycling for failure of stage cementing unit and sealed circulation device |
| CN109707335A (en) * | 2017-10-25 | 2019-05-03 | 中国石油化工股份有限公司 | Completion tubular column and completion method |
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| CN113803019A (en) | 2021-12-17 |
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