CA1062148A - Subsea well installation - Google Patents
Subsea well installationInfo
- Publication number
- CA1062148A CA1062148A CA324,427A CA324427A CA1062148A CA 1062148 A CA1062148 A CA 1062148A CA 324427 A CA324427 A CA 324427A CA 1062148 A CA1062148 A CA 1062148A
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- CA
- Canada
- Prior art keywords
- plug
- cementing
- stage
- string
- shut
- 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.)
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Abstract
ABSTRACT
Apparatus for multiple stage cementing of well casing in subsea wells. Also, a subsea stage cementer, plug stack assembly. The combination with a subsea stage cementer, plug stack assembly of a packing and shipping crate therefor.
Apparatus for multiple stage cementing of well casing in subsea wells. Also, a subsea stage cementer, plug stack assembly. The combination with a subsea stage cementer, plug stack assembly of a packing and shipping crate therefor.
Description
1(~6~148 SUBSEA WELL INSTALLATION
- This invention relates to subsea well installations, espe-cially oil or gas wells.
This is a divisional applica~ional of Serial No. 276,937.
Heretofore, casing strings have been cemented in well 5 bores in multiple stages. In multiple stage cementing, a first stage or first increment of cement slurry is pumped down the well casing string, out through first stage cementing ports adjacent the bottom of the string, and into the well bore.
- The slurry rises in the annular space between the casing and lD'3the well bore to a predetermined level, and is there maintained in a quiescent condition until it sets. A second stage or second increment of cement slurry is pumped down the casing, out through second stage cementing ports, and into the well bore at a level at or above the top of the column of first 15 stage cement. The second stage of slurry rises in the annulus between the casing and the well bore to a second predetermined level, and is maintained quiescent while setting. Sometimes, a third or even a fourth stage of cement slurry is introduced into the annulus above a preceding stage. The cement bonds J 20 the casing to the walls of the well and prevents migration of fluids through the annulus.
Multiple stage cementing has many advantages over single stage cementing, in which but a single charge of cement slurry is deposited around the entire length of casing.
A multiple stage cementing operation reduces the likeli-,. . - :: i :.
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14~3 hood of breaking down a weak earth formation with the hi~h fluid pressures required to lift a long signle column of cement slurry, thus minimizing the loss of slurry to thieving formations. Such a cementing procedure reduces the required 5 pump pressures to magnitudes lower than those needed for a corresponding single stage job.
~ qultiple stage operations also reduce the length of travel of the slurry in contact with the earth formations surrounding the casing, to thereby reduce contamination of the slurry and 10 insure the strength of the cement when it has cured.
Such multiple stage procedures reduce the quantity of ; cement required to cement widely separated intervals, as in dual zone wells.
~ultiple stage cementing reduces channeling of the cement 15 slurry into drilling mud in the annulus, thereby providing a stronger bond of the cement with the case and the earth formations.
One previously known system for multiple stage cementing is described in Composite Catalog of Oil Field Equipment and 20 Services, 31st Revision (1974-75), published by World Oil, a Gulf Publishing Company Publication, Houston, Texas, U.S.~., 1974, pages 334 to 341. Another such system is described in the foregoing Composite Catalog on pages 2434 to 2440. These known systems employ a casing string having a first-stage 25 cementing port device disposed near the bottom of the $tring, and a stage collar disposed at an intermediate location in the string. First stage cementing plug structures are used in con-nection with the first stage cementing port device. Other plugs .: :
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are used to open and close the ports of the stage cementing collar.
These known systems are practicable for use in cementing casing in the bores of land based wells, where the top of 5 the casing is adjacent to the earth's surface, and the plugs can be launched directly into the top of the casing string.
However, these systems are not easily adapted for use in cement-ing casing in marine based or subsea wells,where the top of the casing terminates at the ocean floor, which may be many 10 hundreds of feet below the surface of the water at which the drilling vessel or platform is located. In those instances, the casing string has to be extended from the ocean floor up to the floating drilling vessel or platform though a riser pipe, so that the plugs can be launched into the casing. The modi-15 fications required for adapting these known systems to marineoperations are time-consuming and costly.
A subsea well stage cementing system is disclosed in applicant's prior U.S. Patent No. 3,730,267 issued May 1, 1973.
In the system of that prior patent, the top of the casing string '~ 20 terminates at the ocean floor, and fluid connection to the floating or stationary platform at the surface o~ the water is established through a string of drill pipe. A stage cementing collar is located in the casing string at an intermediate point. A hollow top plug for the first stage of cement slurry 25 is releasably positioned in the casing string belo~ the stage cementing collar. The normally closed stage ce~enting collar is opened for the second stage cementing operation by dropping an opening~ball into the string of drill pipe and allowing it .. . . . ~ ,.. .
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--4--to drop to the stage collar, and thereafter applying fluid pressure in the casing string above the stage collar. A dart-actuated, hollow top plug for the second stage of cement slurry is releasably secured to a hollow mandrel adjacent to the top 5 of the casing string. This dart-actuated top plug also serves to close the ports of the stage cementing collar after the second stage of cement slurry has heen expelled into the an-nulus in the well bore.
A principal shortcoming of the system of the foregoing 10 prior patent is that, prior to conducting the second stage of cementing, there is no provision for wiping the interior walls of the casing string above the stage collar to remove adherent cement slurry left thereon by the first stage of cement slurry.
The time that elapses between the first and second stages of 15 cementing may be such that the adherent cement slurry sets up on the interior walls of the casing, thereby to interfere with subsequent operations. Moreover, the first- and second-stage cementing plugs are mounted in the casing string at widely separated locations, which entails two plug-mounting steps.
20 ~lso, due to the narrowness of the bore of the string of drill pipe, it is not practicable to drop a trip-plug therethrou~h to open the stage collar.
The invention resides in a subsea well installation in-cluding a composite well casing string suspended within a sub-25 sea well bore from a casing hanger supported by a subsea wellhead, said composite well casing string being adapted to be connected through running tool ~eans and a string o~ drill pipe to hoisting and cementing equipment dispQsed adjacent to the , ~
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surface of the sea above the well head; said composite well casing string having first-stage cementing port means for communicating the interior of said composite string with the : exterior and adapted to be closed by a first-stage cementing 5 plug; and initially closed, but openable and closeable second-stage cementing port means for communicating the interior of said casing string with the exterior, said second-stage cementing port means being disposed above said first-stage cementing port means and below the top of said casing string 10 and adapted to be opened by a trip-plug and cloased by a shut-off plug; a mandrel extending longitudinally into the well casing string and providing a longitudinal passage in fluid communication with the string of drill pipe- a shut-off plug : in the well casing string and adapted to close said second-15 stage cementing port means; first releasable means connecting ~: said shut-off plug to said mandrel; a trip-plug in the well casing string and adapted to open said second stage cementing ~: port means; second releasable means connecting said trip-plug directly to said shut-off plug; a first-stage cementing plug 20 in the well casing string and adapted to close said first-stage cementing port means; third releasable means connecting said first-stage cementing plug directly to said trip-plug, means defining a passage through each plug for the flow of cementing fluids from the longitudinal passage of the mandrel into the 25 well casing string; said first-stage cementing plug having means copperative with a first closure member in said cementing fluid to close the passage in said first-stage cementing plug and effect release of said third releasable means responsive ~ .
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to cementing fluid pressure to launch said first~stage cement-ing port means; said trip-plug having means cooperative with a second closure member in said cementing fluid to close the passage in said trip-plug to effect release of said second 5 releasable means res2onsive to cementing fluid pressure to launch said trip-plug for travel down said casing string to open said second-stage cementing port means; and said shut-off plug having means cooperative with a third closure member in said cementing fluid to close the passage in said shut-off 10 plug and effect release of said first releasable means re-sponsive to cementing fluid pressure to launch said shut-off plug for travel down said casing string to close said second-stage cementing port means.
Other aims, features and advantages of the invention are 15 set forth in or will be apparent from the following detailed description of preferred embodiments taken in connection with the accompanying drawings.
In the drawings:
-; Fig. 1 is a vertical sectional view, partly in elevation, 20 of the uppermost part of a marine well, and showing a drilling vessel afloat in the water above the well, important components of the well installation, and exemplary components of cementing equipment in accordance with the invention;
Fig. 2 is a vertical sectional View on a larger scale o~
25 a part of the well shown in Fig.l;
Figs. 3A, 3B and 3C are, respectively, views of an upPer part, an intermediate part, and a lower part of the well of Fi~.
1, with certain components of the equip~ent of the in~ention . . . - - . . ". . : . - -. .
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4~1 installed therein preparatory to the introduction of cement slurry;
Figs. 4A, 4B and 4C are, respectively, views similar to the views of Figs. 3A, 3B and 3C, but subsequent to the placement 5 of the first stage of cement slurry, Figs. 5A, 5B and 5C are, respectively, views similar to those seen in Figs. 4A, 4B and 4C, but with the stage collar conditioned Eor the placement of the second stage of cement slurry;
Figs. 6A, 6B and 6C are, resepctively, views similar to those of Figs. 5A, 5B and 5C, but subsequent to the placement of the second stage of cement slurry;
Fig. 7 is an enlarged, quarter-sectional view of a plug stack assembly in accordance with the invention;
Fig. 8 is an elevational view of actuators for the plugs of the plug stack assembly of Fig. 7;
Fig. 9 is an axial sectional view, partly in elevation, of a trip plug in accordance with the invention;
Fig. 10 is a longitudinal sectional view taken along the 20 line 10-10 of Fig. 11 of a crated plug stack assembly of the invention, the plug stack being shown in elevation;
Fig. 11 is a sectional view taken along the line 11-11 of Fig. 10 and looking in the direction of the arrows, and Fig. 12 is an axial sectional view of a swivel component 25 of the cementing equipment.
Referring to the drawings, particularly to Fig. 1, there is shown a well 21 which has been drilled into the earth 22 beneath the sea 23 or other body of water. A subsea wellhead - :
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structure 23 is emplaced on the floor 25 of the sea at the top of the well. Suspended in the well from the well head is a string of well casing 2~ having inserted therein a plug stack assembly 27, to be described in detail hereinafter. A
5 riser pipe 28 is connected to the wellhead by a quickly re-leasable connector 29 and communicates with the casing string through passages in the well head. The riser pipe extends up through the water to a drilling ship or vessel 31 floating on the surface 32 of the sea directly over the wellhead. The 10 riser pipe extends up through an opening or moonhole (not shown) in the ship, and the top (not shown) of the riser pipe is exposed above the waterline and within the vessel. A string of drill pipe 33 extends within the riser pipe 28 upwardly from the connector 29 and terminates at the top in an actuator 15 launching head 34 accessible from the deck 35 of the drilling vessel. A bumper sub 36 is included in the string of drill pipe to compensate for the heaving of the vessel due to wave action. The drilling vessel is equipped with a derrick struc-ture 37. Guide lines 38 extend between the vessel 31 and the . .
20 wellhead structure 24. The riser pipe 28 may have a blowout preventer stack (not shown) located above and closely adjacent - t~ the quickly releasable connector 29.
Turning now to Fig. 2, it is seen that the wellhead structure 24 generally includes an annular support member 39 25 wh~ch is affixed to the upper end of an outer casing 41 and has vertically extending guide posts 42 slidably receiving guide tubes 43 which are guided on the lines 38,pxeviously described. The riser pipe 28 is secured to a wellhead body .~ .
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g 44 by the previously mentioned connector 29. This connector is well-known and includes releasable latch dogs 45 shiftable to inner positions to secure the connector 29 on the well-head body 44 in response to movement of an annular latch pis-5 ton 46 downwardly, the latch dogs 45 being releasable upon up-ward movement of the latch piston 46. Piston chambers 47 and 48 are provided and are adapted to be pressurized through respective conduits 49 and 51 to shift the piston upwardly and downwardly, as desired. The riser pipe 28 is connected to the 10 quickly releasable connector 29 by fasteners 52.
A universal running tool 53 is threadedly connected to the lower end of the drill string 33, and a casing hanger body 54 is threaded to the running tool. The well casing string 26 is threadedly fastened to the bottom of the casing hanger 15 body 54. The casing string 26 is run into the well on the drill pipe string 33 until the casing hanger body 54 lands upon a casing hanger 55 supported by the wellhead body 44.
Grooves 56 are provided in the casing hanger 55 to allow cir-culation of fluids from the annulus 57 below the casing hanger 20 body 54 into the riser pipe 28 thereabove.
~ The wellhead structure described hereinbe~ore 1s~cQnyen~
-~ tlonal and needs no further deta~led description herein.
As best seen if Fig. 2, a plug launching mandrel 58 de-pends from the universal running tool 53. This ~andrel has an 25 upper mandrel section 59 connected to the running tool by threads 61. At its lower end, the mandrel section 59 connects with a swivel, designated b~ the general reference numeral 62, to be described in detail hereinafter with reference to Fig. 12.
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A lower mandrel section 63 extends downwardly from the swivel 62 and is connected at its bottom end to a shut-off plug 64.
A surge chamber 65, also to be described hereinafter, surrounds the lower mandrel section 63 between the shut-off plug 64 and the swivel 62. At the bottom of the shut-off plug there is 5 connected a trip plug 66, which, in turn, carries a first-stage cementing plug 67. These three pluas will be described more fully hereinafter, but it is here remarked that these plugs are received within the top portion of the well casing string 26.
~eferring to Fig. 12, the s~ivel 62 connects the upper mandrel section 59 to the lower mandrel section 63 to permit relative rotation o.f the two sections about their common longi-tudinal axis, so that the universal running tool 53 can be screwed into the casing hanger body 54 without rotating the 15 plugs 64,66 and 67 in the casing string 26. For this purpose, the uppoer mandrel section 59 has a lower cylindrical end 68 rotatably received within an upwardly extended end 69 of the lower mandrel section 63. Suitable seal means 71 may be pro-vided between the mandrel section ends 68 and 69. The swivel .. ~ 20 means further includes outturned flanges 72 and 73 on the re-spective mandrel sections 59 and 63, these flanges being held together for relative rotation by a split, channeled ring 7~, which is retained in place by a collar 75 held in place by a ~ : -. snap ring 76.
The surge chamber 65 ~s shown In CrOsS se.ction in ~ig. 3A, to which reference is now made. The surge chambe.r ha~s. an upper head 77 that is threaded to the lower mandrel section 63 by .
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thread means 78. An O-ring seal 79 provides a static seal between the upper head 77 and the lower mandrel section 63.
A cylindrical body portion 81 is welded at ~2 to the upper head 77. A lower head 83 is welded at 84 to the bottom of 5 the body portion 81 and is sealed to the lower mandrel section 63 by another O-ring seal 85. The upper and lower heads and the cylindrical body portion cooperate with the lower mandrel section to provide an annular space 86. This annular space is in fluid ocmmunication through ports 87 with the bore 88 10 of the lower mandrel section. The ports slope downwardly and inwardly and are located at the bottom of the annular space 86 to permit liquid to drain from the annular space into the bore of the lower mandrel section.
~he bottom of the lower mandrel section 63 has exterior 15 threads 89 to which a bushing 91 is secured by mating interior threads. An O-ring seal 92 seals the bushing to the lower mandrel section.
As best seen in Figs. 3A and 7,'the shut-off plug 64, previously referred to, has an inner body 93 with an upstanding 20 bell 94 of enlarged diameter that surrounds the bushing 91 and has a sliding fit therewith. The bell is releasably secured to the bushing by circumferentially arranged shear pins 95 and is sealed to the bushing by an Q-ring 96. A seri,es, of l~ngi-tudinally spaced, rubber cups 97 is ~ounted on the central part 25 98 of the inner body 93. The cups have upwardly and out~ardly sloped flanges 99 that yieldingly engage the inner wall of the well casing 26. Retainer rings 101 hold the cups and space them along the central part of the body. The uppermost cup 97 - .: . ~ : . .
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10~4~3 is retained in an annular T-slot provided between the bell 94 and the upper ring 101; the middle cup is held in an annular T-slot provided between the upper and lower retainer rings;
and the bottommost cup is held in an annular T-slot provided 5 between the lower retainer ring and a nose piece 102. The nose piece is fastened by threads 103 to the bottom of the inner body 93 of the shut-off plug 64, an O-ring 104 being provided to seal the nose piece to the inner body. The nose piece is fitted with a downwardly tapering, rubber sealing 10 rings 105, the purpose of which will be set forth hereinafter.
It will be seen that the inner body 93 provides an axial passage 106 that communicates with the bore 88 of the lower mandrel section.
The trip-plug 66, previously referred to and shown to 15 advantage in Figs. 3A and 7, has a body portion 107 with an upstanding bell 108 of larger diameter and a depending nose portion 109 of smaller diameter. The bell 108 slidably engages a reduced diameter portion 111 of the nose piece 102 of the superjacent shut-off plug 64, and is releasably attached thereto 20 by circumferentially arranged shear pins 112. The bell 108 is sealed to the reduced diameter portion by an O-ring 113. A
downwardly tapered sealing ring 114 is mounted on the bell 108 of the trip-plug. The body portion 107 has relatively thick walls that are spaced radially inwardly from the bore of the 25 casing 26 and that provide a central liquid flo~ passage 115 communicating with the passa~e la6 in the shut-Qff plug immedi-ately thereabove.
The first-stage ce~enting plug 67, previously mentioned . .
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and now described with reference to Figs. 3A and 7, is re-leasably suspended from the trip-plug 66. The first-stage cementing plug has an inner body 116 with an upstanding bell 117 of enlarged diameter. The bell 117 is slidably fitted on 5 the nose portion lO9 of the superjacent trip-plug 66 and is releasably secured thereto by a circular row of shear pins llO.
An O-ring 100 seals the bell 117 to the nose portion 109.
Threaded at 118 to the bottom of the inner body 116 is a nose piece ll9 having an axial opening 121 therethrough. The axial 10 opening 121 communicates fluidically w;th a bore 122 in the inner body 116, which, in turn, is in fluid communication with the passage 115 in the trip-plug. A plurality, specifically three, elastomeric cups 123a, 123b and 123c are mounted on the inner body 116 of the first-stage cementing plug. The cups 15 have upwardly and outwardly sloped ~langes 124 that are in ` flex'ble engagement with the inner wall of the casing 26. Cup 123a is mounted in an annular T-slot provided between retainer rings 125a and 125b. Cup 123b is similarly mounted between retainer rings 125b and 125c. In like fashion, cup 123c is 20 mounted between retainer rings 125c and 125d. A rubber flange number 126 is mounted between the retainer ring 125d and the ~ nose piece 119, which is threaded to the inner body 116 and - which secures the retainer rings and the elastomeric cups upon the inner body.
As best seen in Fig. 3B, a stage cementing collar, desig-nated by the general reference numeral 127, is located in the casing string 26 below the plug stac~ assembly 27 and at a depth where it is desired to introduce the second stage of - - - - . , . ~.
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cement slurry into the annulus 57 between the casing and the wall of the well 21. The stage cementing collar has a tubular body 128, the upper, internal end o:f which has tapered threads 129 engaged with mating threads 131 on the exterior 5 of the casing 26. The bottom of the boay 127 has tapered, external threads 132 that are threaded into the mating threads 133 of a casing collar 134. The casing collar is threadedly coupled at 135 to a lower extension of the casing string 26.
Thus, the body 128 of the casing collar provides, in effect, 10 a continuous joint of the casing string. An outer sleeve 136 is secured to the body 128 by threads 137~ and is sealed to the body by an O-ring 138. Stage cementing ports 139 are provided in the body 128, and ports 141 are provided in the outer sleeve 136 and arranged in alignment with ports 139.
The body 128 has a central portion 142 of reduced outer : diameter that provides with the outer sleeve 136 an annular cylindrical chamber 143. It is seen that the O-ring 138, previously mentioned, is above the chamber 143 and thus seals the top of the chamber against leakage between the threads 20 137. Openings 144 extend fromthe top of the cha~ber 143 in-wardly through the central portion 142 of the body 128. The lower part of the annular chamber 143 is enlarged to form an annular chamber portion 145. A port 146 in the outer sleeye 136 communicates the annular chamber portion 145 with the well-25 casing annulus 57.
Slidably disposed within the annular cylindrical chamber 143 and above the ports 139, 141, is a shut-ofg sleeve 147.
Shear pins 148, circumferentially disposed, releasably secure - - . - .
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the shut-off sleeve to the central portion 142 oE the body 128.
An O-ring 149 is floatingly disposed in the annular cylindrical chamber 143 and on top of the shut-off sleeve 147 to provide a seal between the shut-off sleeve and the walls of the annular 5 chamber. Ratch notches 151 are circumscribed on the outer periphery of the central portion 142 of the body. A split detent ring 152, received in a circumferential groove 153 on the inner periphery of the shut-off sleeve 147, is adapted to spring into engagement with one of the ratch notches 151 10 when the shut-off sleeve is in a lower position, thereby to hold the shut-off sleeve in said lower position.
Just below the ports 139, an O-ring 154 is positioned in a circumferential groove in the outer surface of the central portion 142 of the body. This O-ring is retained in 15 its groove by a surrounding O-ring retainer sleeve 155 re-leasably fastened to the central portion 142 by shear pins 156.
The shut~off sleeve has an annular tapered counterbore 157 provided in its bottom portion, for a purpose which will be explained hereinafter.
20 Slidably mounted within the central portion 142 of the body 128 is lower or port opening sleeve 158. This sleeve is re-leasably held by shear pins 159 in a position to close the ports 139. This lower sleeve has circumferential O-rings 161 and 162 ~ positioned, respectively, above and below the ports 139 to seal - 25 the sleeve to the central portion 142 above and below the ports.
A tapered stop member 163 is provided adjacent to the bottom of the lower sleeve 158. This stop member is adapted to abut the upper/ stepped surface 164 of a split stop ring 165 when the . .
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lower sleeve 158 moves downwardly, thereby to limit such down-ward movement. The stop ring 165 is received in a groove 166 in the bore of the body 128. The bore 167 of the lower sleeve is circumscribed at the top by a chamfer 168 which forms a 5 seat for an actuator or trip-plug, which will be described hereinafter.
Immediately superjacent to the lower sleeve 158 an upper or port-closing sleeve 169 is slidably mounted in the body 128.
This sleeve carries an O-ring 171 in a groove around its outer 10 surface for sealing the sleeve to the bore of the body. The upper sleeve is releasably pinned to the bore of the body 128 by shear pins 172, and, when the shear pins are broken, is adapted to slide downwardly in the bore of the body. A cham-fer 173 circumscribes the top of the vertical passage 174 15 through the upper sleeve, this chamfer forming a seat for an actuator or shut-off plug, to be described hereinafter.
It will be seen from Fig. 3B that the diameter of the seat or chamfer 168 on the lower sleeve 158 is greater than the diameter of the bore 167 of the lower sleeve, yet less than 2a the diameter of the vertical passage 174 through the upper i sleeve 169, which, in turn, has a diameter less than the seat or chamfer 173 of the upper sleeve. The reasons for these diametral relationships will be set forth hereinafter.
As will be seen from Figs. 3B and 3C, the casing 26 ex-25 tends downwardly in the well 21 to a cement float collar 175.This float collar is conventional. It has a tubular body 176 - threaded at 177 to the casing 26, and at 178 to a casing coupling 179.
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A block of concrete 181 is cast within the body 176 and about a cage 182 to support the cage centrally of the body. The cage has an upper fluid passageway 183 having a valve seat 184 at its lower end. The passageway 183 communicates fluidi-5 cally with the casing 26 thereabove through a duct 185 pro-vided in the cement block. The cage has a fluid passage 186 at the bottom. A plurality of upstanding arcuately spaced ribs 187 is provided at the bottom of the cage, and a ball valve 188 is seen, in Fig. 3, resting on the ribs. Fluid may flow 10 downwardly throught the float collar 175, passing through the passages 185, 183 and 186, and flowing past the ball valve 188 throught the spaces between the ribs 187. Upward flow of fluid throught the float collar will be stopped by the seating of the valve ball 188 on the valve seat 184 (see Fig. 4C).
Referring further to Fig. 3C, a length of casing 26 is threaded at 189 into the casing collar 179, previously referred to, and extends to a depth near the bottom 191 of the well 21.
~` A cement float show 192 is secured to the bottom of the casing 26 by a threaded connection 193. This float shoe is similar in 20 construction and operation to the float collar 175 described in the immediately preceding paragraph. From a consideration of Fig. 3C taken with the foregoing description,it will be ap~
arent that fluid can flow down through the float show 192 and out into the well bore, but that return flow from the well bore 25 up through the float shoe into the casing will be prevented by the seating of the ball valve 194 on the valve seat 195.
Turnin~ now to Fig. 7, the plug stack assembly 27 is seen in quarter section. In this view, the rubber flanges 99 and - , ,. . ~ . ~ , .
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106~:14~3 124 of the shut-off plug 64 and the first-stage cementing plug 67, respectively, are shown in their unflexed condition. It will also be seen that the trip-plug 66 is provided with cir-cumferentially spaced, longitudinal grooves 196 on the outer 5 surface of the body portion 107 which facilitate the fall of this plug through a column of liquid in the well casing 26.
As seen in Fig. 7, the plug stack assembly 27 is fitted with a discoid assembly plate 197 overlying the bushing 91 and the bell 94 of the shut-off plug 64. The assembly plate has 10 a central hold 198 through which a tie rod 199 extends. The end 201 of the tie rod is threaded and fitted with a comple-mentary threaded nut 202. Another discoid assembly plate 203 is disposed at the other ena of the plug stack assembly in a-butting relation to the free end o the nose piece 119. The 15 assembly plate 203 has a central hole 204 through which the other end 205 of the tie rod 199 projects, such other end being threaded and fitted with a nut 206.
The plug stack assembly may be put together in the fol-lowing manner. The plugs 64, 66 and 67 and the bushing 91 20 initially do not have holes for the shear pins 95, 112 and 110.
The bushing 91 with its O-ring 96 is fitted into the bell portion 94 of the shut-off plug 64. The reduced diameter por-t~on 111 of the shut-off plug 64 with its O-ring 113 is inserted into the bell 108 o~ the trip-plug 66, with the annular surface 25 207 on the shut-off plu~ in abutment with the cooperating an-nular sur~ace 208 on the trip-plug. Then, the nose portion 109 of the trip-plug 66, ~ith its O-rin~ 100 is inserted into the bell 117 of the first-st~ge ce~enting plug 67. The coop-~.. . .. ...
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erating annular surfaces 209 on the trip-plug and 211 on the first-stage cementing plug 67 are placed in abutting relation. Thereafter, the tie rod 199 is disposed through the assembly of plugs, the assembly plates 197 and 203 are placed 5 on the tie rod, and the nuts 202 and 206 are threaded on the ends of the tie rod and tightened to hold the assembly to-gether. Thereafter, the holes for the shear pins 95, 112 and 110 are drilled, and the shear pins inserted in the re-spective holes.
As shown in Figs. 10 and 11, the completed plug stack assembly 27, for purposes of storage or shipment, is packed in a crate designated by the general reference numeral 212.
The crate has a lower half 213 and an upper half 214. Only the lower half need be described, as the upper half is iden-15 tical to it. The lower half has an elongated rectangularbottom panel 215 and two opposed upstanding side panels 216 and 217, integral with suitably joined to the bottom panel.
End panels 218 and 219 are provided for the lower half of the crate. A spacer 221 is located in the left end of the lower 20 half of the crate, as seen in Fig. 10. This spacer abuts the assembly plate 197 of the plug stack assembly, and prevents the latter from moving to the left. A notch 222 i5 cut in the spacer to accommodate the end of the tie rod 199 and the nut 202. A similar spacer or end support member 223 is provided 25 at the right-hand end of the lower half of the crate to contact the assembly plate 203 and prevent the stack assembly from moving to the right. A notch 224 is provided in the space~
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A central bulkhead 225 is mounted between the bottom panel 215 and the side panels 216 and 127. This bulkhead has a semicircular notch 226 contoured to the trip-plug 66 to cradle the latter. A similar bulkhead 227 supports the 5 bell 94 of the shut-off plug 64. In like fashion, another bulkhead 228 is arranged to support the first-stage cementing plug 67.
The upper half 214 of the crate is placed on the lower half 213, as seen in Fig. 11, and a number of steel bands 10 229a, 229b,229c and 229d are passed about the crate, tight-ened, and fastened by buckles 231a, 231b, 231c and 231d.
It will be understood that the tie rod means holds the plus stack in compression and keeps the shear pins substant-ially free from stresses. The crate 212, with its bulkheads 15 and spacers, supports the plug stack assembly in a manner to ~ prevent bending and longitudinal shifting of the plug stack - assembly, thereby further protecting the shear pins from damage. It will also be understood that the tie rod means is removed from the plug stack assembly before the assembly is 20 fitted to the lower section 63 of the plug launching mandrel in preparation for a stage cementing operation.
Actuators or plug closure devices for the se~eral plugs of the plug stack assembly 27 are illustrated ;n Fig. 8 ! to which reference is now made. The actuator for the first-25 stage cementing plug 67 is deslgnated by the general refer~ence numeral 232, that for the trip-plug 66 by the general reference numeral 233 and that for the shut-off plu~ 64 by the general reference numeral 234.
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The actuator 232 is shown in side elevation in Fig. 8 and takes the form of a dart. In Fig. 4C, the dart is shown in longitudinal section and seated in the bore of the first-stage cementing lug 67. The dart has a metal body 235, 5 preferably formed of an easily drillable metal such as alumi-num or magnesium alloy. The body has a shank 236. a flange 237 adapted to enter the bore 122 of the plug 67 and to be-come seated upon a seat 238 provided in the bore 122, and a nose portion 239 adapted to be received with a close sliding 10 fit in a reduced diameter section 241 of the bore to main-tain the dart aligned with the plug 67 when the dart seated.
A unitary, elastomeric outer portion 242 is bonded to the shank 236 . The outer portion has a forward wiper cup 243 adjacent to the flange 237 and a rear wiper cup 244 at the 15 back. Intermediate the wiper cups 243 and 244 is a seal cup 245 having a substantially smaller diameter than the wiper cups. The wiper cups and the seal cup extend outwardly and rearwardly from a longitudinal portion 246 of the elasto-- meric outer portion 242.
- 20 The wiper cups have equal diameters so~ewhat larger than the inside diameter of the drill pipe string 33 and are adapted to form a good running seal w~i,th the inner w~ll$ of the drill pipe string and to wipe these inner w,all,s when pumped down the drill pipe string as de$cribed hereinafter.
25 These wiper cups will also enable the dart to be p~m,ped through the bores of the uni~ersal running tool 53, the mandrel ~, sections 59 and 63, and the plugs 64 and 66 and to wipe these bores. When the dart is seated in the first-stage cementing ~:
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plug 67, the bore 122 of which has a smaller diameter than the bore of the drill pipe string 33, the wiper cups are folded back to such an extent that they become fluted like a folded umbrella and do not provide a very e~fective seal with the 5 bore 122 of the first-stage cementing plug. The seal cup 245 has a diameter somewhat greater than the diameter of the bore 122, and is adapted to be slightly compressed in the bore without being distorted sufficiently to become fluted; in this way the seal cup 245 forms an effective seal with the 10 bore 122. As seen in Fig. 4C, the seal cup 245 is spaced rearwardly from the root of the forward wiper cups 243 far enough to allow the forward wiper cup to collapse into the - longitudinal rubber portion 246 without substantially over-lapping the seal cup 245 and without breaking the seal be-15 tween the latter and the bore 122. As exemplary of the di-mensions involved: where the inside diameter of the drill pipe 33 is 3-5/8 inches and the inside diameter of the bore 122 of the first-stage cementing plug is 2 inches, the outside diameter of the wiper cups 243 and 244 may be 4-3/4 inches and 20 the outside diameter of the seal cup 245 may be 2-1/4 inches.
The actuator 233 for the trip-plug 66 and its manner of cooperation with the trip plug will be described with reference to Figs. 8, 9 and 4A. Referring particularly to Fig. 9, the trip-plug 66 is shown prior to the drilling therein of holes - 25 for the shear pins 110 and 112, previously mentioned. The body portion 107 is tubular and is adapted to receive the actuator 233 within its bore, as shown in Fig. 4A. The act-uator has a head 247, a shank 248, a downwardly tapering portion :
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249, and a truncated conical nose 251. The shank 248 is pro-vided with an annular sealing ring groove 252 of L-shaped cross section. The upright portion 253 of the groove tapers downwardly to meet the deeper cut horizontal portion 254 of 5 the groove. A rubber or elastomeric sealing ring 255, of conforming L-shaped cross section is disposed within the groove 252. The bottom 256 of the sealing ring has the same outside diameter as the shank 248, and it flares upwardly and outwardly to form a shoulder 257 that extends outwardly from 10 the shank. At the bottom of the head 247, there is provided a shoulder 258 that tapers inwardly to intersect the shank 248.
The bore of the trip-plug 66 has a reduced diameter sec-tion 259a, 259b adapted to slidingly receive the shank 248 of the actuator 233 and to align the actuator with the bore 15 of the trip plug. Within the reduced diameter section is provided a downwardly tapering groove 261 having a downwardly facing shoulder 262 at the top. A counterbore 253 is pro-vided above the reduced diameter section 259a and an upwardly facing, tapered shoulder 264 is formed between the counter-20 bore and the reduced diameter section 259a. The bore of thetrip plug has an enlarged cylindrical section 265 extending ; from the reduced diameter section 259b to the bottom of the plug. When the actuator 233 is inserted into the bore of the trip-plug 66 from the top, as seen in Fig. 4A, the head 247 25 is received in the counterbore 263 with the shoulder 258 a-butting the shoulder 264 to stop downward movement of the ac-tuator. The rubber sealin~ ring 255 is received In the tapered - groove 261 to seal thereagainst while the shoulder 257 at the .
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-- 106;~14~3 top of the sealing ring underlies the shoulder 262 at the top of the groove to retain the actuator in the bore of the plug so that it cannot be removed upwardly. The tapered portions 249 and 251 of the actuator project into the cylindrical 5 section 265 of the bore.
The trip-plug 66 and the actuator 233 may be made of cast iton, which has a relatively high specific gravity,yet is read-ily drillable. The high specific gravity of the actuator 233 enables it to fall reasonably rapidly through liquid in 10 the drill pipe string, and the high speciflc gravity of the combined trip-plu~ and actuator provide a rapid rate of fall through liquid in the casing, as will be described hereinafter.
The easy drillability of the trip-plug and its actuator make ; it easy to remove these elements by drilling them from the 15 casing following the cementing operation.
The actuator or closure member 234 for the shut-off plug 64 is shown in side elevation in Fig. 8 and in longitudinal cross section in Fig. 6B. The actuator has a body 266 of an easily drillable metal, such as magnesium alloy. The body 20 has a shank 267 and a nose portion 268, slidably received in the axial passage 106 of the shut off plug 64. A flange 269 on the body has a downwardly facing shoulder 271 that abuts a a shoulder 272 in the axial pas$age 106 to limit downward move~
ment of the actuator. A rubber or elastomeric cup assembly 25 273 is molded about and bonded to the shank 267 and the upper surface of the flange 269. Upwardly and outwardly flaring cups -274a, 274b and 274c are provided, these being of a diameter adequate to wipe the interior of the drill pipe string 33 as it - -:- ., . - : ' i ' - '' :' ' ,.: ~
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Referring to Fig. 2, the actuator launching head 34 has an 5 elongated cylindrical chamber 275 that communicates downwardly with the bore of the drill pipe string 33. An easily re-movable cap 276 is threaded on the top of the head. A pipe fitting 277 is provided in the side of the launching head and is connectible to a pumping system (not shown) for pump-10 ing various fluids into the head and down the drill pipestring. An actuator, such as the actuator 232 is introduced into the top of the chamber 275 with the cap 276 removed, the cap then being replaced. The actuator is releasably retained in place by a pin detent 278 slidable in a cylinder 279 and 15 retractable by a handle 281 to release the actuator to permit it to drop into the liquid in the chamber 275. Any suitable launching head may be used, such as the one that accommodates three-plug actuators at one time.
The o~eration of the stage cement~ng equi,pment o~ the in-20 vention will now be described. The equipment is assembledand positioned in the well as shown in Figs. 1, 2, 3A, 3B and -~ and 3C.
The li~uid pumping system is connected to the pipe fitting 277, and the well may be conditioned for cementing as by pump-25 ing a clear conditioning fluid down the drill pipe string andplug stack assembly, down the casing string, out through the float shoe and up the annulus and riser pipe to flush drilling mud from the well.
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` - io6;~1 4~3 Next, a first stage of cement slurry, the volume of which has been calculated to fill the well annulus from the bot-tom of the hole to a level just below the stage cementer ports 139, 141 is pumped down the drill pipe casing followed by 5 displacing fluid which may be water. As the tail end of the first stage of cement slurry passes through the actuator launching head 34, the latch 278 is retracted to release the actuator dart 232 which, being driven by the displacing fluid behind it, follows the first stage of cement slurry down the 10 string of drill pipe 33, and, as it travels, wiping the inner walls of the drill pipe free from cement slurry. The actuator or dart 232 is of such a size that it passes through the opening in the universal running tool, through the mandrel 58, through the axial passage 106 in the shut-off plug 64, 15 through the passage 115 of the trip-plug, and seats on the seat 238 in the bore 122 of the first-stage cementing plug to close the bore therethrough, as previously descrîbed. The pressure pulse induced in the displacing fluid behind the actuator 232 when it suddenly seats is cushioned by the compre-20 ssion of air in the surge chamber 65, so that the first-stage cementing plug is not jarred loose from the trip-plug 66. The pump pressure on the displacing liquid is increased to a value at which the shear pins 110 are sheared to release the first-stage cementing plug from the trip-plug. The trip-plug with 25 its actuator are displaced down the casing string by the fur-ther pumping of displacing fluid until the first-stage cement-ing plug comes to rest on the float collar 175, as seen in Fig. 4C. In this portion, the flange member 126 of the first-. .
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stage cementing plug seals against the top surface 282 of thefloat collar. This causes an increase in pump pressure, which indicates that the first stage of cement slurry 283 has been displaced into the well annulus, as seen in Figs. 4C and 5 4B. The rubber flanges 124 of the first-stage cementing plug in moving down the casing string will have wiped the bore of the casing string clear of cement slurry. The pumps may now be stopped, whereupon the ball valves 188 and 194 will be moved into contact with their respective seats 184 10 and 195 to prevent any appreciable reverse flow of cement slurry from the well annulus back into the casing string, and to maintain the first-stage of cement slurry in position in the annulus until it sets.
- A second stage of cement slurry may then be emplaced in 15 the well annulus above the first-stage of cement. It is - first necessary to open the stage cementing ports 139, 141 from the closed condition, as shown in Figs. 3B and 4B, and to plug the bore of the casing below these ports. To ac-complish this, the trip-plug actuator or trip-plug bar 233 is 20 dropped through the actuator launching head 34 into the column of displacing fluid in the drill pipe string and the casing.
The bar gravitates through the static column of displacing '! fluid in the drill pipe string, down through the axial passage 106 of the shut-off plug 64, and into the passage 115 of the 25 trip-plug 66. Pump pressure is then applied to the displacing liquid to seat the trip-plug bar in the trip-plug with the shoulder 258 of the head 247 abutting the shoulder 264 in the trip-plug and the sealing ring 255 i`~n ~ealing relat~n to the ' ,. . . . . .
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~6;~14t3 downwardly tapering groobe 261, as previously described, to thereby close the passage 115. Pump pressure is increased sufficiently to break the shear pins 112 and release the trip-plug 66 with its actuator 233 from the shut-off plug 64, 5 as shown in Fig. 4A.
; When the trip-plug and its actuator have been launched, as aEoresaid, the pumps are stopped, and the trip-plug and its actuator are permitted to fall as a unit through the dis-placing fluid in the casing string into the lower sleeve 158 10 of the stage cementing collar 127; see Fig. 5B. The trip-plug is stopped inthe lower sleeve when the tapered sealing ring 114 of the trip-plug is received on the chamfered surface 168 or seat at the top of the lower sleeve, thereby closing the bore 167 through the lower sleeve. Pump pressure is applied 15 to the displacing fluid to breakdthe shear pins 159 and allow ~- the lower sleeve to move down to the position shown in Fig. 5s to open the stage cementing ports 139 and 141. ~1hen the ports have been opened, the pumps are stopped.
; The required volume of a second stage of cement slurry is 20 now pumped into the actuator launching head 34 through the - fitting 277, followed by a second stage of displacing fluid, ~ which may be water. The actuator 234 for the shut-off plug 64, - the actuator previously having been loaded into the actuator launching head, is released into the interface between the 25 second stage of cement slurry and the second stage of displa-cing fluid which follows it. Pumping is continued to drive the actuator 234 down the drill pipe string 33, through the passage 284 in the universal launching tool 53, down through the mandrel , .
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06;~48 58 and into the axial passage 106 of the shut-off plug 64.
The actuator 234 lands on the shoulder 272 in the passage 1~6 of the shut-off plug, thereby closing the passage. The shock pulse setup in the second stage of displacing fluid when the 5 actuator seats on the shoulder 272 is cushioned in the surge chamber 65. Pump pressure is increased to break the shear pins 95 and separate the shut-off plug 64 from the bushing 91, which remains attached to the lower mandrel section 63, as seen in Fig. 6A.
The shut-off plug actuator 234,as it is pumped down the drill pn~pe string 33, separates the second displacement fluid from the second stage of cement slurry. This actuator also wipes the interior walls of the drill pipe string to remove cement slurry therefrom.
After the shut-off plug 64 with its actuator have been launched from the mandrel 58, pumping is continued to drive the second stage of cement slurry 285 down the casing and out through the ports 139 , 141 in the stage cementing collar and into the well-casing annulus 57 above the first stage 20 cement 283. The shut-off plug acts as a piston which is moved by the second displacement fluid and which drives the - second stage of cement slurry ahead of it. In moving down the casingl the rubber cups 97 of the shut-off plug wipe the interior walls of the casing. Fluid is returned to the sur-25 face from the annulus 21 through the grooves 56 in the universal running tool 53 and through the riser pipe 28.
When the shut off plug reaches the stage cementing collar 127, the second stage of cement slurry will have been emplaced - - . . - .. .. ~ . ~ ... . - - - .
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in the annulus 57. The shut-off plug then functions the upper sleeve to close the cementing ports 139,141.
These ports are shown in the open position in Fig. 5B and in the closed position in Fig. 6s. The shut-off plug lands in 5 the upper sleeve 169 of the stage cementing collar, the sealing ring 105 of the shut-off plug sealing against the chamfer 173 of the sleeve. Pump pressure is increased to shear the shear pins 172 and move the upper sleeve downward to abut the lower sleeve 158 and close the ports 139,141,as seen in Fig. 6B.
A further increase in pump pressure moves the shut-off sleeve 147 from the position shown in Fig. 5B down to the position shown in Fig. 6s to permanently close the ports 139, 141 so that they will remain closed after the bore of the stage cementing collar has been drilled out. This is effected 15 by increasing the pump pressure so that the hydraulic pressure in the annular cylindrical chamber 143 produces a downward force on the shut-off sleeve sufficient to break the shear pins 148 and alllow the shut-off sleeve to be moved to its lower position as seen in Fig. 6B. In moving downwardly, the 20 shut-off sleeve contacts the retainer sleeve 155, breaking the shear pins 156, and moving the retainer sleeve from its Fig. 5B
position to its Fig. 6B position. The O-ring 154 is thereby uncovered and immediately thereafter is covered by the shut-off sleeve to seal the latter to the central portion 142 of the 25 stage cementing collar 127. The counterbore 157 in the bottom of the shut-off sleeve enables the shut-off sleeve to easily ride over and seal against the O-ring 154. The shut-off sleeve is held in its port-closing position by engagement of - ~
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the split detent ring 152 in one of the ratch notches 151.
When the ports 139,141 have been closed, the second stage of cement is allowed to set in the annulus 57. The universal running tool 53 and drill pipe string 33 are un-5 screwed from the casing hanger body 54 and retrieved throughthe riser pipe 28. Thereafter, the stage cementing collar 127, the cement float collar 175, and the cement float shoe 192 may be drilled through, and futher operations conducted in the well.
It will be understood that the shear pins 110 releasably retaining the first-stage cementing plug 67 on the trip-plug are designed to part and release the first-stage cementing plug in response to a force substantially less than the force needed to part the shear pins 112 and effect launching of the 15 trip-plug 66. In turn, the force required to break the shear pins 112 is substantially less than that which is effective to part the shear pins 95 that releasably retain the shut-off plug 64 on bhe bushi~g 91. Accordingly, the first-stage ce-; menting plug 67 can be launched without breaking the shear 20 pins 112 and 95. Then, the trip-plug 66 can be launched without breaking the shear pins 95. Thereafter, the shut-off plug can be launched.
Releasable devices other than shear pins may be employed for releasably mounting one or more of the plugs in the plug 25 stack assembly 27. For example, and without limitation thereto, a double collet release mechanism, such as that disclosed in U.S. Patent 3,915,226, issued October 28, 1975, could be used in lieu of shear pins.
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Moreover, actuators or closure members, other than those shown in Fig. 8, may be substituted for the actuators speci-fically disclosed. Actuators, such as solid or elastomeric balls, may be employed to advantage.
It is generally advantageous to use a drop bar or gravity type actuator, such as the drop bar 233, to launch the trip-plug, because the drop bar can be used long after the first stage of cement has been emplaced in the annulus. However, a dart or other pum~-down closure member may be used instead 10 of the drop bar to launch the trip-plug, provided it is timed to land in and launch the trip-plug just before the first-stage cementing plug closes the opening 185 in the float collar 175.
~ Although the present invention is partiaularly adapted - 15 for stage cementing marine wells, it may also be used for stage cementing land based wells.
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- This invention relates to subsea well installations, espe-cially oil or gas wells.
This is a divisional applica~ional of Serial No. 276,937.
Heretofore, casing strings have been cemented in well 5 bores in multiple stages. In multiple stage cementing, a first stage or first increment of cement slurry is pumped down the well casing string, out through first stage cementing ports adjacent the bottom of the string, and into the well bore.
- The slurry rises in the annular space between the casing and lD'3the well bore to a predetermined level, and is there maintained in a quiescent condition until it sets. A second stage or second increment of cement slurry is pumped down the casing, out through second stage cementing ports, and into the well bore at a level at or above the top of the column of first 15 stage cement. The second stage of slurry rises in the annulus between the casing and the well bore to a second predetermined level, and is maintained quiescent while setting. Sometimes, a third or even a fourth stage of cement slurry is introduced into the annulus above a preceding stage. The cement bonds J 20 the casing to the walls of the well and prevents migration of fluids through the annulus.
Multiple stage cementing has many advantages over single stage cementing, in which but a single charge of cement slurry is deposited around the entire length of casing.
A multiple stage cementing operation reduces the likeli-,. . - :: i :.
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14~3 hood of breaking down a weak earth formation with the hi~h fluid pressures required to lift a long signle column of cement slurry, thus minimizing the loss of slurry to thieving formations. Such a cementing procedure reduces the required 5 pump pressures to magnitudes lower than those needed for a corresponding single stage job.
~ qultiple stage operations also reduce the length of travel of the slurry in contact with the earth formations surrounding the casing, to thereby reduce contamination of the slurry and 10 insure the strength of the cement when it has cured.
Such multiple stage procedures reduce the quantity of ; cement required to cement widely separated intervals, as in dual zone wells.
~ultiple stage cementing reduces channeling of the cement 15 slurry into drilling mud in the annulus, thereby providing a stronger bond of the cement with the case and the earth formations.
One previously known system for multiple stage cementing is described in Composite Catalog of Oil Field Equipment and 20 Services, 31st Revision (1974-75), published by World Oil, a Gulf Publishing Company Publication, Houston, Texas, U.S.~., 1974, pages 334 to 341. Another such system is described in the foregoing Composite Catalog on pages 2434 to 2440. These known systems employ a casing string having a first-stage 25 cementing port device disposed near the bottom of the $tring, and a stage collar disposed at an intermediate location in the string. First stage cementing plug structures are used in con-nection with the first stage cementing port device. Other plugs .: :
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are used to open and close the ports of the stage cementing collar.
These known systems are practicable for use in cementing casing in the bores of land based wells, where the top of 5 the casing is adjacent to the earth's surface, and the plugs can be launched directly into the top of the casing string.
However, these systems are not easily adapted for use in cement-ing casing in marine based or subsea wells,where the top of the casing terminates at the ocean floor, which may be many 10 hundreds of feet below the surface of the water at which the drilling vessel or platform is located. In those instances, the casing string has to be extended from the ocean floor up to the floating drilling vessel or platform though a riser pipe, so that the plugs can be launched into the casing. The modi-15 fications required for adapting these known systems to marineoperations are time-consuming and costly.
A subsea well stage cementing system is disclosed in applicant's prior U.S. Patent No. 3,730,267 issued May 1, 1973.
In the system of that prior patent, the top of the casing string '~ 20 terminates at the ocean floor, and fluid connection to the floating or stationary platform at the surface o~ the water is established through a string of drill pipe. A stage cementing collar is located in the casing string at an intermediate point. A hollow top plug for the first stage of cement slurry 25 is releasably positioned in the casing string belo~ the stage cementing collar. The normally closed stage ce~enting collar is opened for the second stage cementing operation by dropping an opening~ball into the string of drill pipe and allowing it .. . . . ~ ,.. .
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--4--to drop to the stage collar, and thereafter applying fluid pressure in the casing string above the stage collar. A dart-actuated, hollow top plug for the second stage of cement slurry is releasably secured to a hollow mandrel adjacent to the top 5 of the casing string. This dart-actuated top plug also serves to close the ports of the stage cementing collar after the second stage of cement slurry has heen expelled into the an-nulus in the well bore.
A principal shortcoming of the system of the foregoing 10 prior patent is that, prior to conducting the second stage of cementing, there is no provision for wiping the interior walls of the casing string above the stage collar to remove adherent cement slurry left thereon by the first stage of cement slurry.
The time that elapses between the first and second stages of 15 cementing may be such that the adherent cement slurry sets up on the interior walls of the casing, thereby to interfere with subsequent operations. Moreover, the first- and second-stage cementing plugs are mounted in the casing string at widely separated locations, which entails two plug-mounting steps.
20 ~lso, due to the narrowness of the bore of the string of drill pipe, it is not practicable to drop a trip-plug therethrou~h to open the stage collar.
The invention resides in a subsea well installation in-cluding a composite well casing string suspended within a sub-25 sea well bore from a casing hanger supported by a subsea wellhead, said composite well casing string being adapted to be connected through running tool ~eans and a string o~ drill pipe to hoisting and cementing equipment dispQsed adjacent to the , ~
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surface of the sea above the well head; said composite well casing string having first-stage cementing port means for communicating the interior of said composite string with the : exterior and adapted to be closed by a first-stage cementing 5 plug; and initially closed, but openable and closeable second-stage cementing port means for communicating the interior of said casing string with the exterior, said second-stage cementing port means being disposed above said first-stage cementing port means and below the top of said casing string 10 and adapted to be opened by a trip-plug and cloased by a shut-off plug; a mandrel extending longitudinally into the well casing string and providing a longitudinal passage in fluid communication with the string of drill pipe- a shut-off plug : in the well casing string and adapted to close said second-15 stage cementing port means; first releasable means connecting ~: said shut-off plug to said mandrel; a trip-plug in the well casing string and adapted to open said second stage cementing ~: port means; second releasable means connecting said trip-plug directly to said shut-off plug; a first-stage cementing plug 20 in the well casing string and adapted to close said first-stage cementing port means; third releasable means connecting said first-stage cementing plug directly to said trip-plug, means defining a passage through each plug for the flow of cementing fluids from the longitudinal passage of the mandrel into the 25 well casing string; said first-stage cementing plug having means copperative with a first closure member in said cementing fluid to close the passage in said first-stage cementing plug and effect release of said third releasable means responsive ~ .
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to cementing fluid pressure to launch said first~stage cement-ing port means; said trip-plug having means cooperative with a second closure member in said cementing fluid to close the passage in said trip-plug to effect release of said second 5 releasable means res2onsive to cementing fluid pressure to launch said trip-plug for travel down said casing string to open said second-stage cementing port means; and said shut-off plug having means cooperative with a third closure member in said cementing fluid to close the passage in said shut-off 10 plug and effect release of said first releasable means re-sponsive to cementing fluid pressure to launch said shut-off plug for travel down said casing string to close said second-stage cementing port means.
Other aims, features and advantages of the invention are 15 set forth in or will be apparent from the following detailed description of preferred embodiments taken in connection with the accompanying drawings.
In the drawings:
-; Fig. 1 is a vertical sectional view, partly in elevation, 20 of the uppermost part of a marine well, and showing a drilling vessel afloat in the water above the well, important components of the well installation, and exemplary components of cementing equipment in accordance with the invention;
Fig. 2 is a vertical sectional View on a larger scale o~
25 a part of the well shown in Fig.l;
Figs. 3A, 3B and 3C are, respectively, views of an upPer part, an intermediate part, and a lower part of the well of Fi~.
1, with certain components of the equip~ent of the in~ention . . . - - . . ". . : . - -. .
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4~1 installed therein preparatory to the introduction of cement slurry;
Figs. 4A, 4B and 4C are, respectively, views similar to the views of Figs. 3A, 3B and 3C, but subsequent to the placement 5 of the first stage of cement slurry, Figs. 5A, 5B and 5C are, respectively, views similar to those seen in Figs. 4A, 4B and 4C, but with the stage collar conditioned Eor the placement of the second stage of cement slurry;
Figs. 6A, 6B and 6C are, resepctively, views similar to those of Figs. 5A, 5B and 5C, but subsequent to the placement of the second stage of cement slurry;
Fig. 7 is an enlarged, quarter-sectional view of a plug stack assembly in accordance with the invention;
Fig. 8 is an elevational view of actuators for the plugs of the plug stack assembly of Fig. 7;
Fig. 9 is an axial sectional view, partly in elevation, of a trip plug in accordance with the invention;
Fig. 10 is a longitudinal sectional view taken along the 20 line 10-10 of Fig. 11 of a crated plug stack assembly of the invention, the plug stack being shown in elevation;
Fig. 11 is a sectional view taken along the line 11-11 of Fig. 10 and looking in the direction of the arrows, and Fig. 12 is an axial sectional view of a swivel component 25 of the cementing equipment.
Referring to the drawings, particularly to Fig. 1, there is shown a well 21 which has been drilled into the earth 22 beneath the sea 23 or other body of water. A subsea wellhead - :
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structure 23 is emplaced on the floor 25 of the sea at the top of the well. Suspended in the well from the well head is a string of well casing 2~ having inserted therein a plug stack assembly 27, to be described in detail hereinafter. A
5 riser pipe 28 is connected to the wellhead by a quickly re-leasable connector 29 and communicates with the casing string through passages in the well head. The riser pipe extends up through the water to a drilling ship or vessel 31 floating on the surface 32 of the sea directly over the wellhead. The 10 riser pipe extends up through an opening or moonhole (not shown) in the ship, and the top (not shown) of the riser pipe is exposed above the waterline and within the vessel. A string of drill pipe 33 extends within the riser pipe 28 upwardly from the connector 29 and terminates at the top in an actuator 15 launching head 34 accessible from the deck 35 of the drilling vessel. A bumper sub 36 is included in the string of drill pipe to compensate for the heaving of the vessel due to wave action. The drilling vessel is equipped with a derrick struc-ture 37. Guide lines 38 extend between the vessel 31 and the . .
20 wellhead structure 24. The riser pipe 28 may have a blowout preventer stack (not shown) located above and closely adjacent - t~ the quickly releasable connector 29.
Turning now to Fig. 2, it is seen that the wellhead structure 24 generally includes an annular support member 39 25 wh~ch is affixed to the upper end of an outer casing 41 and has vertically extending guide posts 42 slidably receiving guide tubes 43 which are guided on the lines 38,pxeviously described. The riser pipe 28 is secured to a wellhead body .~ .
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g 44 by the previously mentioned connector 29. This connector is well-known and includes releasable latch dogs 45 shiftable to inner positions to secure the connector 29 on the well-head body 44 in response to movement of an annular latch pis-5 ton 46 downwardly, the latch dogs 45 being releasable upon up-ward movement of the latch piston 46. Piston chambers 47 and 48 are provided and are adapted to be pressurized through respective conduits 49 and 51 to shift the piston upwardly and downwardly, as desired. The riser pipe 28 is connected to the 10 quickly releasable connector 29 by fasteners 52.
A universal running tool 53 is threadedly connected to the lower end of the drill string 33, and a casing hanger body 54 is threaded to the running tool. The well casing string 26 is threadedly fastened to the bottom of the casing hanger 15 body 54. The casing string 26 is run into the well on the drill pipe string 33 until the casing hanger body 54 lands upon a casing hanger 55 supported by the wellhead body 44.
Grooves 56 are provided in the casing hanger 55 to allow cir-culation of fluids from the annulus 57 below the casing hanger 20 body 54 into the riser pipe 28 thereabove.
~ The wellhead structure described hereinbe~ore 1s~cQnyen~
-~ tlonal and needs no further deta~led description herein.
As best seen if Fig. 2, a plug launching mandrel 58 de-pends from the universal running tool 53. This ~andrel has an 25 upper mandrel section 59 connected to the running tool by threads 61. At its lower end, the mandrel section 59 connects with a swivel, designated b~ the general reference numeral 62, to be described in detail hereinafter with reference to Fig. 12.
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A lower mandrel section 63 extends downwardly from the swivel 62 and is connected at its bottom end to a shut-off plug 64.
A surge chamber 65, also to be described hereinafter, surrounds the lower mandrel section 63 between the shut-off plug 64 and the swivel 62. At the bottom of the shut-off plug there is 5 connected a trip plug 66, which, in turn, carries a first-stage cementing plug 67. These three pluas will be described more fully hereinafter, but it is here remarked that these plugs are received within the top portion of the well casing string 26.
~eferring to Fig. 12, the s~ivel 62 connects the upper mandrel section 59 to the lower mandrel section 63 to permit relative rotation o.f the two sections about their common longi-tudinal axis, so that the universal running tool 53 can be screwed into the casing hanger body 54 without rotating the 15 plugs 64,66 and 67 in the casing string 26. For this purpose, the uppoer mandrel section 59 has a lower cylindrical end 68 rotatably received within an upwardly extended end 69 of the lower mandrel section 63. Suitable seal means 71 may be pro-vided between the mandrel section ends 68 and 69. The swivel .. ~ 20 means further includes outturned flanges 72 and 73 on the re-spective mandrel sections 59 and 63, these flanges being held together for relative rotation by a split, channeled ring 7~, which is retained in place by a collar 75 held in place by a ~ : -. snap ring 76.
The surge chamber 65 ~s shown In CrOsS se.ction in ~ig. 3A, to which reference is now made. The surge chambe.r ha~s. an upper head 77 that is threaded to the lower mandrel section 63 by .
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thread means 78. An O-ring seal 79 provides a static seal between the upper head 77 and the lower mandrel section 63.
A cylindrical body portion 81 is welded at ~2 to the upper head 77. A lower head 83 is welded at 84 to the bottom of 5 the body portion 81 and is sealed to the lower mandrel section 63 by another O-ring seal 85. The upper and lower heads and the cylindrical body portion cooperate with the lower mandrel section to provide an annular space 86. This annular space is in fluid ocmmunication through ports 87 with the bore 88 10 of the lower mandrel section. The ports slope downwardly and inwardly and are located at the bottom of the annular space 86 to permit liquid to drain from the annular space into the bore of the lower mandrel section.
~he bottom of the lower mandrel section 63 has exterior 15 threads 89 to which a bushing 91 is secured by mating interior threads. An O-ring seal 92 seals the bushing to the lower mandrel section.
As best seen in Figs. 3A and 7,'the shut-off plug 64, previously referred to, has an inner body 93 with an upstanding 20 bell 94 of enlarged diameter that surrounds the bushing 91 and has a sliding fit therewith. The bell is releasably secured to the bushing by circumferentially arranged shear pins 95 and is sealed to the bushing by an Q-ring 96. A seri,es, of l~ngi-tudinally spaced, rubber cups 97 is ~ounted on the central part 25 98 of the inner body 93. The cups have upwardly and out~ardly sloped flanges 99 that yieldingly engage the inner wall of the well casing 26. Retainer rings 101 hold the cups and space them along the central part of the body. The uppermost cup 97 - .: . ~ : . .
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10~4~3 is retained in an annular T-slot provided between the bell 94 and the upper ring 101; the middle cup is held in an annular T-slot provided between the upper and lower retainer rings;
and the bottommost cup is held in an annular T-slot provided 5 between the lower retainer ring and a nose piece 102. The nose piece is fastened by threads 103 to the bottom of the inner body 93 of the shut-off plug 64, an O-ring 104 being provided to seal the nose piece to the inner body. The nose piece is fitted with a downwardly tapering, rubber sealing 10 rings 105, the purpose of which will be set forth hereinafter.
It will be seen that the inner body 93 provides an axial passage 106 that communicates with the bore 88 of the lower mandrel section.
The trip-plug 66, previously referred to and shown to 15 advantage in Figs. 3A and 7, has a body portion 107 with an upstanding bell 108 of larger diameter and a depending nose portion 109 of smaller diameter. The bell 108 slidably engages a reduced diameter portion 111 of the nose piece 102 of the superjacent shut-off plug 64, and is releasably attached thereto 20 by circumferentially arranged shear pins 112. The bell 108 is sealed to the reduced diameter portion by an O-ring 113. A
downwardly tapered sealing ring 114 is mounted on the bell 108 of the trip-plug. The body portion 107 has relatively thick walls that are spaced radially inwardly from the bore of the 25 casing 26 and that provide a central liquid flo~ passage 115 communicating with the passa~e la6 in the shut-Qff plug immedi-ately thereabove.
The first-stage ce~enting plug 67, previously mentioned . .
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and now described with reference to Figs. 3A and 7, is re-leasably suspended from the trip-plug 66. The first-stage cementing plug has an inner body 116 with an upstanding bell 117 of enlarged diameter. The bell 117 is slidably fitted on 5 the nose portion lO9 of the superjacent trip-plug 66 and is releasably secured thereto by a circular row of shear pins llO.
An O-ring 100 seals the bell 117 to the nose portion 109.
Threaded at 118 to the bottom of the inner body 116 is a nose piece ll9 having an axial opening 121 therethrough. The axial 10 opening 121 communicates fluidically w;th a bore 122 in the inner body 116, which, in turn, is in fluid communication with the passage 115 in the trip-plug. A plurality, specifically three, elastomeric cups 123a, 123b and 123c are mounted on the inner body 116 of the first-stage cementing plug. The cups 15 have upwardly and outwardly sloped ~langes 124 that are in ` flex'ble engagement with the inner wall of the casing 26. Cup 123a is mounted in an annular T-slot provided between retainer rings 125a and 125b. Cup 123b is similarly mounted between retainer rings 125b and 125c. In like fashion, cup 123c is 20 mounted between retainer rings 125c and 125d. A rubber flange number 126 is mounted between the retainer ring 125d and the ~ nose piece 119, which is threaded to the inner body 116 and - which secures the retainer rings and the elastomeric cups upon the inner body.
As best seen in Fig. 3B, a stage cementing collar, desig-nated by the general reference numeral 127, is located in the casing string 26 below the plug stac~ assembly 27 and at a depth where it is desired to introduce the second stage of - - - - . , . ~.
.
cement slurry into the annulus 57 between the casing and the wall of the well 21. The stage cementing collar has a tubular body 128, the upper, internal end o:f which has tapered threads 129 engaged with mating threads 131 on the exterior 5 of the casing 26. The bottom of the boay 127 has tapered, external threads 132 that are threaded into the mating threads 133 of a casing collar 134. The casing collar is threadedly coupled at 135 to a lower extension of the casing string 26.
Thus, the body 128 of the casing collar provides, in effect, 10 a continuous joint of the casing string. An outer sleeve 136 is secured to the body 128 by threads 137~ and is sealed to the body by an O-ring 138. Stage cementing ports 139 are provided in the body 128, and ports 141 are provided in the outer sleeve 136 and arranged in alignment with ports 139.
The body 128 has a central portion 142 of reduced outer : diameter that provides with the outer sleeve 136 an annular cylindrical chamber 143. It is seen that the O-ring 138, previously mentioned, is above the chamber 143 and thus seals the top of the chamber against leakage between the threads 20 137. Openings 144 extend fromthe top of the cha~ber 143 in-wardly through the central portion 142 of the body 128. The lower part of the annular chamber 143 is enlarged to form an annular chamber portion 145. A port 146 in the outer sleeye 136 communicates the annular chamber portion 145 with the well-25 casing annulus 57.
Slidably disposed within the annular cylindrical chamber 143 and above the ports 139, 141, is a shut-ofg sleeve 147.
Shear pins 148, circumferentially disposed, releasably secure - - . - .
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the shut-off sleeve to the central portion 142 oE the body 128.
An O-ring 149 is floatingly disposed in the annular cylindrical chamber 143 and on top of the shut-off sleeve 147 to provide a seal between the shut-off sleeve and the walls of the annular 5 chamber. Ratch notches 151 are circumscribed on the outer periphery of the central portion 142 of the body. A split detent ring 152, received in a circumferential groove 153 on the inner periphery of the shut-off sleeve 147, is adapted to spring into engagement with one of the ratch notches 151 10 when the shut-off sleeve is in a lower position, thereby to hold the shut-off sleeve in said lower position.
Just below the ports 139, an O-ring 154 is positioned in a circumferential groove in the outer surface of the central portion 142 of the body. This O-ring is retained in 15 its groove by a surrounding O-ring retainer sleeve 155 re-leasably fastened to the central portion 142 by shear pins 156.
The shut~off sleeve has an annular tapered counterbore 157 provided in its bottom portion, for a purpose which will be explained hereinafter.
20 Slidably mounted within the central portion 142 of the body 128 is lower or port opening sleeve 158. This sleeve is re-leasably held by shear pins 159 in a position to close the ports 139. This lower sleeve has circumferential O-rings 161 and 162 ~ positioned, respectively, above and below the ports 139 to seal - 25 the sleeve to the central portion 142 above and below the ports.
A tapered stop member 163 is provided adjacent to the bottom of the lower sleeve 158. This stop member is adapted to abut the upper/ stepped surface 164 of a split stop ring 165 when the . .
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lower sleeve 158 moves downwardly, thereby to limit such down-ward movement. The stop ring 165 is received in a groove 166 in the bore of the body 128. The bore 167 of the lower sleeve is circumscribed at the top by a chamfer 168 which forms a 5 seat for an actuator or trip-plug, which will be described hereinafter.
Immediately superjacent to the lower sleeve 158 an upper or port-closing sleeve 169 is slidably mounted in the body 128.
This sleeve carries an O-ring 171 in a groove around its outer 10 surface for sealing the sleeve to the bore of the body. The upper sleeve is releasably pinned to the bore of the body 128 by shear pins 172, and, when the shear pins are broken, is adapted to slide downwardly in the bore of the body. A cham-fer 173 circumscribes the top of the vertical passage 174 15 through the upper sleeve, this chamfer forming a seat for an actuator or shut-off plug, to be described hereinafter.
It will be seen from Fig. 3B that the diameter of the seat or chamfer 168 on the lower sleeve 158 is greater than the diameter of the bore 167 of the lower sleeve, yet less than 2a the diameter of the vertical passage 174 through the upper i sleeve 169, which, in turn, has a diameter less than the seat or chamfer 173 of the upper sleeve. The reasons for these diametral relationships will be set forth hereinafter.
As will be seen from Figs. 3B and 3C, the casing 26 ex-25 tends downwardly in the well 21 to a cement float collar 175.This float collar is conventional. It has a tubular body 176 - threaded at 177 to the casing 26, and at 178 to a casing coupling 179.
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A block of concrete 181 is cast within the body 176 and about a cage 182 to support the cage centrally of the body. The cage has an upper fluid passageway 183 having a valve seat 184 at its lower end. The passageway 183 communicates fluidi-5 cally with the casing 26 thereabove through a duct 185 pro-vided in the cement block. The cage has a fluid passage 186 at the bottom. A plurality of upstanding arcuately spaced ribs 187 is provided at the bottom of the cage, and a ball valve 188 is seen, in Fig. 3, resting on the ribs. Fluid may flow 10 downwardly throught the float collar 175, passing through the passages 185, 183 and 186, and flowing past the ball valve 188 throught the spaces between the ribs 187. Upward flow of fluid throught the float collar will be stopped by the seating of the valve ball 188 on the valve seat 184 (see Fig. 4C).
Referring further to Fig. 3C, a length of casing 26 is threaded at 189 into the casing collar 179, previously referred to, and extends to a depth near the bottom 191 of the well 21.
~` A cement float show 192 is secured to the bottom of the casing 26 by a threaded connection 193. This float shoe is similar in 20 construction and operation to the float collar 175 described in the immediately preceding paragraph. From a consideration of Fig. 3C taken with the foregoing description,it will be ap~
arent that fluid can flow down through the float show 192 and out into the well bore, but that return flow from the well bore 25 up through the float shoe into the casing will be prevented by the seating of the ball valve 194 on the valve seat 195.
Turnin~ now to Fig. 7, the plug stack assembly 27 is seen in quarter section. In this view, the rubber flanges 99 and - , ,. . ~ . ~ , .
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106~:14~3 124 of the shut-off plug 64 and the first-stage cementing plug 67, respectively, are shown in their unflexed condition. It will also be seen that the trip-plug 66 is provided with cir-cumferentially spaced, longitudinal grooves 196 on the outer 5 surface of the body portion 107 which facilitate the fall of this plug through a column of liquid in the well casing 26.
As seen in Fig. 7, the plug stack assembly 27 is fitted with a discoid assembly plate 197 overlying the bushing 91 and the bell 94 of the shut-off plug 64. The assembly plate has 10 a central hold 198 through which a tie rod 199 extends. The end 201 of the tie rod is threaded and fitted with a comple-mentary threaded nut 202. Another discoid assembly plate 203 is disposed at the other ena of the plug stack assembly in a-butting relation to the free end o the nose piece 119. The 15 assembly plate 203 has a central hole 204 through which the other end 205 of the tie rod 199 projects, such other end being threaded and fitted with a nut 206.
The plug stack assembly may be put together in the fol-lowing manner. The plugs 64, 66 and 67 and the bushing 91 20 initially do not have holes for the shear pins 95, 112 and 110.
The bushing 91 with its O-ring 96 is fitted into the bell portion 94 of the shut-off plug 64. The reduced diameter por-t~on 111 of the shut-off plug 64 with its O-ring 113 is inserted into the bell 108 o~ the trip-plug 66, with the annular surface 25 207 on the shut-off plu~ in abutment with the cooperating an-nular sur~ace 208 on the trip-plug. Then, the nose portion 109 of the trip-plug 66, ~ith its O-rin~ 100 is inserted into the bell 117 of the first-st~ge ce~enting plug 67. The coop-~.. . .. ...
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erating annular surfaces 209 on the trip-plug and 211 on the first-stage cementing plug 67 are placed in abutting relation. Thereafter, the tie rod 199 is disposed through the assembly of plugs, the assembly plates 197 and 203 are placed 5 on the tie rod, and the nuts 202 and 206 are threaded on the ends of the tie rod and tightened to hold the assembly to-gether. Thereafter, the holes for the shear pins 95, 112 and 110 are drilled, and the shear pins inserted in the re-spective holes.
As shown in Figs. 10 and 11, the completed plug stack assembly 27, for purposes of storage or shipment, is packed in a crate designated by the general reference numeral 212.
The crate has a lower half 213 and an upper half 214. Only the lower half need be described, as the upper half is iden-15 tical to it. The lower half has an elongated rectangularbottom panel 215 and two opposed upstanding side panels 216 and 217, integral with suitably joined to the bottom panel.
End panels 218 and 219 are provided for the lower half of the crate. A spacer 221 is located in the left end of the lower 20 half of the crate, as seen in Fig. 10. This spacer abuts the assembly plate 197 of the plug stack assembly, and prevents the latter from moving to the left. A notch 222 i5 cut in the spacer to accommodate the end of the tie rod 199 and the nut 202. A similar spacer or end support member 223 is provided 25 at the right-hand end of the lower half of the crate to contact the assembly plate 203 and prevent the stack assembly from moving to the right. A notch 224 is provided in the space~
to receive the end of the tie rod and the nut 206, '. ,: : ' . .. , ,' ' ' .. ,, ... .. : ~.. .... ..
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A central bulkhead 225 is mounted between the bottom panel 215 and the side panels 216 and 127. This bulkhead has a semicircular notch 226 contoured to the trip-plug 66 to cradle the latter. A similar bulkhead 227 supports the 5 bell 94 of the shut-off plug 64. In like fashion, another bulkhead 228 is arranged to support the first-stage cementing plug 67.
The upper half 214 of the crate is placed on the lower half 213, as seen in Fig. 11, and a number of steel bands 10 229a, 229b,229c and 229d are passed about the crate, tight-ened, and fastened by buckles 231a, 231b, 231c and 231d.
It will be understood that the tie rod means holds the plus stack in compression and keeps the shear pins substant-ially free from stresses. The crate 212, with its bulkheads 15 and spacers, supports the plug stack assembly in a manner to ~ prevent bending and longitudinal shifting of the plug stack - assembly, thereby further protecting the shear pins from damage. It will also be understood that the tie rod means is removed from the plug stack assembly before the assembly is 20 fitted to the lower section 63 of the plug launching mandrel in preparation for a stage cementing operation.
Actuators or plug closure devices for the se~eral plugs of the plug stack assembly 27 are illustrated ;n Fig. 8 ! to which reference is now made. The actuator for the first-25 stage cementing plug 67 is deslgnated by the general refer~ence numeral 232, that for the trip-plug 66 by the general reference numeral 233 and that for the shut-off plu~ 64 by the general reference numeral 234.
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The actuator 232 is shown in side elevation in Fig. 8 and takes the form of a dart. In Fig. 4C, the dart is shown in longitudinal section and seated in the bore of the first-stage cementing lug 67. The dart has a metal body 235, 5 preferably formed of an easily drillable metal such as alumi-num or magnesium alloy. The body has a shank 236. a flange 237 adapted to enter the bore 122 of the plug 67 and to be-come seated upon a seat 238 provided in the bore 122, and a nose portion 239 adapted to be received with a close sliding 10 fit in a reduced diameter section 241 of the bore to main-tain the dart aligned with the plug 67 when the dart seated.
A unitary, elastomeric outer portion 242 is bonded to the shank 236 . The outer portion has a forward wiper cup 243 adjacent to the flange 237 and a rear wiper cup 244 at the 15 back. Intermediate the wiper cups 243 and 244 is a seal cup 245 having a substantially smaller diameter than the wiper cups. The wiper cups and the seal cup extend outwardly and rearwardly from a longitudinal portion 246 of the elasto-- meric outer portion 242.
- 20 The wiper cups have equal diameters so~ewhat larger than the inside diameter of the drill pipe string 33 and are adapted to form a good running seal w~i,th the inner w~ll$ of the drill pipe string and to wipe these inner w,all,s when pumped down the drill pipe string as de$cribed hereinafter.
25 These wiper cups will also enable the dart to be p~m,ped through the bores of the uni~ersal running tool 53, the mandrel ~, sections 59 and 63, and the plugs 64 and 66 and to wipe these bores. When the dart is seated in the first-stage cementing ~:
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plug 67, the bore 122 of which has a smaller diameter than the bore of the drill pipe string 33, the wiper cups are folded back to such an extent that they become fluted like a folded umbrella and do not provide a very e~fective seal with the 5 bore 122 of the first-stage cementing plug. The seal cup 245 has a diameter somewhat greater than the diameter of the bore 122, and is adapted to be slightly compressed in the bore without being distorted sufficiently to become fluted; in this way the seal cup 245 forms an effective seal with the 10 bore 122. As seen in Fig. 4C, the seal cup 245 is spaced rearwardly from the root of the forward wiper cups 243 far enough to allow the forward wiper cup to collapse into the - longitudinal rubber portion 246 without substantially over-lapping the seal cup 245 and without breaking the seal be-15 tween the latter and the bore 122. As exemplary of the di-mensions involved: where the inside diameter of the drill pipe 33 is 3-5/8 inches and the inside diameter of the bore 122 of the first-stage cementing plug is 2 inches, the outside diameter of the wiper cups 243 and 244 may be 4-3/4 inches and 20 the outside diameter of the seal cup 245 may be 2-1/4 inches.
The actuator 233 for the trip-plug 66 and its manner of cooperation with the trip plug will be described with reference to Figs. 8, 9 and 4A. Referring particularly to Fig. 9, the trip-plug 66 is shown prior to the drilling therein of holes - 25 for the shear pins 110 and 112, previously mentioned. The body portion 107 is tubular and is adapted to receive the actuator 233 within its bore, as shown in Fig. 4A. The act-uator has a head 247, a shank 248, a downwardly tapering portion :
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249, and a truncated conical nose 251. The shank 248 is pro-vided with an annular sealing ring groove 252 of L-shaped cross section. The upright portion 253 of the groove tapers downwardly to meet the deeper cut horizontal portion 254 of 5 the groove. A rubber or elastomeric sealing ring 255, of conforming L-shaped cross section is disposed within the groove 252. The bottom 256 of the sealing ring has the same outside diameter as the shank 248, and it flares upwardly and outwardly to form a shoulder 257 that extends outwardly from 10 the shank. At the bottom of the head 247, there is provided a shoulder 258 that tapers inwardly to intersect the shank 248.
The bore of the trip-plug 66 has a reduced diameter sec-tion 259a, 259b adapted to slidingly receive the shank 248 of the actuator 233 and to align the actuator with the bore 15 of the trip plug. Within the reduced diameter section is provided a downwardly tapering groove 261 having a downwardly facing shoulder 262 at the top. A counterbore 253 is pro-vided above the reduced diameter section 259a and an upwardly facing, tapered shoulder 264 is formed between the counter-20 bore and the reduced diameter section 259a. The bore of thetrip plug has an enlarged cylindrical section 265 extending ; from the reduced diameter section 259b to the bottom of the plug. When the actuator 233 is inserted into the bore of the trip-plug 66 from the top, as seen in Fig. 4A, the head 247 25 is received in the counterbore 263 with the shoulder 258 a-butting the shoulder 264 to stop downward movement of the ac-tuator. The rubber sealin~ ring 255 is received In the tapered - groove 261 to seal thereagainst while the shoulder 257 at the .
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-- 106;~14~3 top of the sealing ring underlies the shoulder 262 at the top of the groove to retain the actuator in the bore of the plug so that it cannot be removed upwardly. The tapered portions 249 and 251 of the actuator project into the cylindrical 5 section 265 of the bore.
The trip-plug 66 and the actuator 233 may be made of cast iton, which has a relatively high specific gravity,yet is read-ily drillable. The high specific gravity of the actuator 233 enables it to fall reasonably rapidly through liquid in 10 the drill pipe string, and the high speciflc gravity of the combined trip-plu~ and actuator provide a rapid rate of fall through liquid in the casing, as will be described hereinafter.
The easy drillability of the trip-plug and its actuator make ; it easy to remove these elements by drilling them from the 15 casing following the cementing operation.
The actuator or closure member 234 for the shut-off plug 64 is shown in side elevation in Fig. 8 and in longitudinal cross section in Fig. 6B. The actuator has a body 266 of an easily drillable metal, such as magnesium alloy. The body 20 has a shank 267 and a nose portion 268, slidably received in the axial passage 106 of the shut off plug 64. A flange 269 on the body has a downwardly facing shoulder 271 that abuts a a shoulder 272 in the axial pas$age 106 to limit downward move~
ment of the actuator. A rubber or elastomeric cup assembly 25 273 is molded about and bonded to the shank 267 and the upper surface of the flange 269. Upwardly and outwardly flaring cups -274a, 274b and 274c are provided, these being of a diameter adequate to wipe the interior of the drill pipe string 33 as it - -:- ., . - : ' i ' - '' :' ' ,.: ~
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- ~)6~14~3 is pumped downward therein, and adequate to seal the axial passage 106 of the shut-off plug 64 when it has come to rest therein, as seen in Fig. 6B.
Referring to Fig. 2, the actuator launching head 34 has an 5 elongated cylindrical chamber 275 that communicates downwardly with the bore of the drill pipe string 33. An easily re-movable cap 276 is threaded on the top of the head. A pipe fitting 277 is provided in the side of the launching head and is connectible to a pumping system (not shown) for pump-10 ing various fluids into the head and down the drill pipestring. An actuator, such as the actuator 232 is introduced into the top of the chamber 275 with the cap 276 removed, the cap then being replaced. The actuator is releasably retained in place by a pin detent 278 slidable in a cylinder 279 and 15 retractable by a handle 281 to release the actuator to permit it to drop into the liquid in the chamber 275. Any suitable launching head may be used, such as the one that accommodates three-plug actuators at one time.
The o~eration of the stage cement~ng equi,pment o~ the in-20 vention will now be described. The equipment is assembledand positioned in the well as shown in Figs. 1, 2, 3A, 3B and -~ and 3C.
The li~uid pumping system is connected to the pipe fitting 277, and the well may be conditioned for cementing as by pump-25 ing a clear conditioning fluid down the drill pipe string andplug stack assembly, down the casing string, out through the float shoe and up the annulus and riser pipe to flush drilling mud from the well.
.
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` - io6;~1 4~3 Next, a first stage of cement slurry, the volume of which has been calculated to fill the well annulus from the bot-tom of the hole to a level just below the stage cementer ports 139, 141 is pumped down the drill pipe casing followed by 5 displacing fluid which may be water. As the tail end of the first stage of cement slurry passes through the actuator launching head 34, the latch 278 is retracted to release the actuator dart 232 which, being driven by the displacing fluid behind it, follows the first stage of cement slurry down the 10 string of drill pipe 33, and, as it travels, wiping the inner walls of the drill pipe free from cement slurry. The actuator or dart 232 is of such a size that it passes through the opening in the universal running tool, through the mandrel 58, through the axial passage 106 in the shut-off plug 64, 15 through the passage 115 of the trip-plug, and seats on the seat 238 in the bore 122 of the first-stage cementing plug to close the bore therethrough, as previously descrîbed. The pressure pulse induced in the displacing fluid behind the actuator 232 when it suddenly seats is cushioned by the compre-20 ssion of air in the surge chamber 65, so that the first-stage cementing plug is not jarred loose from the trip-plug 66. The pump pressure on the displacing liquid is increased to a value at which the shear pins 110 are sheared to release the first-stage cementing plug from the trip-plug. The trip-plug with 25 its actuator are displaced down the casing string by the fur-ther pumping of displacing fluid until the first-stage cement-ing plug comes to rest on the float collar 175, as seen in Fig. 4C. In this portion, the flange member 126 of the first-. .
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stage cementing plug seals against the top surface 282 of thefloat collar. This causes an increase in pump pressure, which indicates that the first stage of cement slurry 283 has been displaced into the well annulus, as seen in Figs. 4C and 5 4B. The rubber flanges 124 of the first-stage cementing plug in moving down the casing string will have wiped the bore of the casing string clear of cement slurry. The pumps may now be stopped, whereupon the ball valves 188 and 194 will be moved into contact with their respective seats 184 10 and 195 to prevent any appreciable reverse flow of cement slurry from the well annulus back into the casing string, and to maintain the first-stage of cement slurry in position in the annulus until it sets.
- A second stage of cement slurry may then be emplaced in 15 the well annulus above the first-stage of cement. It is - first necessary to open the stage cementing ports 139, 141 from the closed condition, as shown in Figs. 3B and 4B, and to plug the bore of the casing below these ports. To ac-complish this, the trip-plug actuator or trip-plug bar 233 is 20 dropped through the actuator launching head 34 into the column of displacing fluid in the drill pipe string and the casing.
The bar gravitates through the static column of displacing '! fluid in the drill pipe string, down through the axial passage 106 of the shut-off plug 64, and into the passage 115 of the 25 trip-plug 66. Pump pressure is then applied to the displacing liquid to seat the trip-plug bar in the trip-plug with the shoulder 258 of the head 247 abutting the shoulder 264 in the trip-plug and the sealing ring 255 i`~n ~ealing relat~n to the ' ,. . . . . .
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~6;~14t3 downwardly tapering groobe 261, as previously described, to thereby close the passage 115. Pump pressure is increased sufficiently to break the shear pins 112 and release the trip-plug 66 with its actuator 233 from the shut-off plug 64, 5 as shown in Fig. 4A.
; When the trip-plug and its actuator have been launched, as aEoresaid, the pumps are stopped, and the trip-plug and its actuator are permitted to fall as a unit through the dis-placing fluid in the casing string into the lower sleeve 158 10 of the stage cementing collar 127; see Fig. 5B. The trip-plug is stopped inthe lower sleeve when the tapered sealing ring 114 of the trip-plug is received on the chamfered surface 168 or seat at the top of the lower sleeve, thereby closing the bore 167 through the lower sleeve. Pump pressure is applied 15 to the displacing fluid to breakdthe shear pins 159 and allow ~- the lower sleeve to move down to the position shown in Fig. 5s to open the stage cementing ports 139 and 141. ~1hen the ports have been opened, the pumps are stopped.
; The required volume of a second stage of cement slurry is 20 now pumped into the actuator launching head 34 through the - fitting 277, followed by a second stage of displacing fluid, ~ which may be water. The actuator 234 for the shut-off plug 64, - the actuator previously having been loaded into the actuator launching head, is released into the interface between the 25 second stage of cement slurry and the second stage of displa-cing fluid which follows it. Pumping is continued to drive the actuator 234 down the drill pipe string 33, through the passage 284 in the universal launching tool 53, down through the mandrel , .
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06;~48 58 and into the axial passage 106 of the shut-off plug 64.
The actuator 234 lands on the shoulder 272 in the passage 1~6 of the shut-off plug, thereby closing the passage. The shock pulse setup in the second stage of displacing fluid when the 5 actuator seats on the shoulder 272 is cushioned in the surge chamber 65. Pump pressure is increased to break the shear pins 95 and separate the shut-off plug 64 from the bushing 91, which remains attached to the lower mandrel section 63, as seen in Fig. 6A.
The shut-off plug actuator 234,as it is pumped down the drill pn~pe string 33, separates the second displacement fluid from the second stage of cement slurry. This actuator also wipes the interior walls of the drill pipe string to remove cement slurry therefrom.
After the shut-off plug 64 with its actuator have been launched from the mandrel 58, pumping is continued to drive the second stage of cement slurry 285 down the casing and out through the ports 139 , 141 in the stage cementing collar and into the well-casing annulus 57 above the first stage 20 cement 283. The shut-off plug acts as a piston which is moved by the second displacement fluid and which drives the - second stage of cement slurry ahead of it. In moving down the casingl the rubber cups 97 of the shut-off plug wipe the interior walls of the casing. Fluid is returned to the sur-25 face from the annulus 21 through the grooves 56 in the universal running tool 53 and through the riser pipe 28.
When the shut off plug reaches the stage cementing collar 127, the second stage of cement slurry will have been emplaced - - . . - .. .. ~ . ~ ... . - - - .
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in the annulus 57. The shut-off plug then functions the upper sleeve to close the cementing ports 139,141.
These ports are shown in the open position in Fig. 5B and in the closed position in Fig. 6s. The shut-off plug lands in 5 the upper sleeve 169 of the stage cementing collar, the sealing ring 105 of the shut-off plug sealing against the chamfer 173 of the sleeve. Pump pressure is increased to shear the shear pins 172 and move the upper sleeve downward to abut the lower sleeve 158 and close the ports 139,141,as seen in Fig. 6B.
A further increase in pump pressure moves the shut-off sleeve 147 from the position shown in Fig. 5B down to the position shown in Fig. 6s to permanently close the ports 139, 141 so that they will remain closed after the bore of the stage cementing collar has been drilled out. This is effected 15 by increasing the pump pressure so that the hydraulic pressure in the annular cylindrical chamber 143 produces a downward force on the shut-off sleeve sufficient to break the shear pins 148 and alllow the shut-off sleeve to be moved to its lower position as seen in Fig. 6B. In moving downwardly, the 20 shut-off sleeve contacts the retainer sleeve 155, breaking the shear pins 156, and moving the retainer sleeve from its Fig. 5B
position to its Fig. 6B position. The O-ring 154 is thereby uncovered and immediately thereafter is covered by the shut-off sleeve to seal the latter to the central portion 142 of the 25 stage cementing collar 127. The counterbore 157 in the bottom of the shut-off sleeve enables the shut-off sleeve to easily ride over and seal against the O-ring 154. The shut-off sleeve is held in its port-closing position by engagement of - ~
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the split detent ring 152 in one of the ratch notches 151.
When the ports 139,141 have been closed, the second stage of cement is allowed to set in the annulus 57. The universal running tool 53 and drill pipe string 33 are un-5 screwed from the casing hanger body 54 and retrieved throughthe riser pipe 28. Thereafter, the stage cementing collar 127, the cement float collar 175, and the cement float shoe 192 may be drilled through, and futher operations conducted in the well.
It will be understood that the shear pins 110 releasably retaining the first-stage cementing plug 67 on the trip-plug are designed to part and release the first-stage cementing plug in response to a force substantially less than the force needed to part the shear pins 112 and effect launching of the 15 trip-plug 66. In turn, the force required to break the shear pins 112 is substantially less than that which is effective to part the shear pins 95 that releasably retain the shut-off plug 64 on bhe bushi~g 91. Accordingly, the first-stage ce-; menting plug 67 can be launched without breaking the shear 20 pins 112 and 95. Then, the trip-plug 66 can be launched without breaking the shear pins 95. Thereafter, the shut-off plug can be launched.
Releasable devices other than shear pins may be employed for releasably mounting one or more of the plugs in the plug 25 stack assembly 27. For example, and without limitation thereto, a double collet release mechanism, such as that disclosed in U.S. Patent 3,915,226, issued October 28, 1975, could be used in lieu of shear pins.
.
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Moreover, actuators or closure members, other than those shown in Fig. 8, may be substituted for the actuators speci-fically disclosed. Actuators, such as solid or elastomeric balls, may be employed to advantage.
It is generally advantageous to use a drop bar or gravity type actuator, such as the drop bar 233, to launch the trip-plug, because the drop bar can be used long after the first stage of cement has been emplaced in the annulus. However, a dart or other pum~-down closure member may be used instead 10 of the drop bar to launch the trip-plug, provided it is timed to land in and launch the trip-plug just before the first-stage cementing plug closes the opening 185 in the float collar 175.
~ Although the present invention is partiaularly adapted - 15 for stage cementing marine wells, it may also be used for stage cementing land based wells.
.
.
:' .
Claims (7)
1. A subsea will installation including:
(A) a composite well casing string suspended within a subsea well bore from a casing hanger supported by a subsea well head, said composite well casing string being adapted to be connected through run-ning tool means and a string of drill pipe to hoisting and cementing equipment disposed adjacent to the surface of the sea above the well head;
(B) said composite well casing string having (a) first-stage cementing port means for communi-cating the interior of said composite string with the exterior and adapted to be closed by a first-stage cementing plug; and (b) initially closed, but openable and closeable second-stage cementing port means for communi-cation the interior of said casing string with the exterior, said second-stage cementing port means being disposed above said first-stage cementing port means and below the top of said casing string and adapted to be opened by a trip-plug and closed by a shut-off plug;
(C) a mandrel extending longitudinally into the well casing string and providing a longitudinal passage in fluid communication with the string of drill pipe;
(D) a shut-off plug in the well casing string and adapted to close said second-stage cementing port means;
(E) first releasable means connecting said shut-off plug to said mandrel;
(F) second releasable means connecting said trip-plug directly to said shut-off plug;
(G) a first-stage cementing plug in the well casing string and adapted to close said first stage cementing port means;
(H) third releasable means connecting said first-stage cementing plug directly to said trip-plug;
(I) means defining a passage through each plug for the flow of cementing fluids from the longitudinal passage of the mandrel into the well casing string;
(J) said first-stage cementing plug having means cooper-ative with a first closure member in said cementing fluid to close the passage in said first-stage cementing plug and effect release of said third re-leasable means responsive to cementing fluid pressure to launch said first-stage cementing plug for travel down said casing string to close said firststage cementing port means;
(K) said trip-plug having means cooperative with a second closure member in said cementing fluid to close the passage in said trip-plug to effect release of said second releasable means responsive to cementing fluid pressure to launch said trip-plug for travel down said casing string to open said second-stage cementing port means; and (L) said shut-off plug having means cooperative with a third closure member in said cementing fluid to close the passage in said shut-off plug and effect re-lease of said first releasable means responsive to cementing fluid pressure to launch said shut-off plug for travel down said casing string to close said second-stage cementing port means.
(A) a composite well casing string suspended within a subsea well bore from a casing hanger supported by a subsea well head, said composite well casing string being adapted to be connected through run-ning tool means and a string of drill pipe to hoisting and cementing equipment disposed adjacent to the surface of the sea above the well head;
(B) said composite well casing string having (a) first-stage cementing port means for communi-cating the interior of said composite string with the exterior and adapted to be closed by a first-stage cementing plug; and (b) initially closed, but openable and closeable second-stage cementing port means for communi-cation the interior of said casing string with the exterior, said second-stage cementing port means being disposed above said first-stage cementing port means and below the top of said casing string and adapted to be opened by a trip-plug and closed by a shut-off plug;
(C) a mandrel extending longitudinally into the well casing string and providing a longitudinal passage in fluid communication with the string of drill pipe;
(D) a shut-off plug in the well casing string and adapted to close said second-stage cementing port means;
(E) first releasable means connecting said shut-off plug to said mandrel;
(F) second releasable means connecting said trip-plug directly to said shut-off plug;
(G) a first-stage cementing plug in the well casing string and adapted to close said first stage cementing port means;
(H) third releasable means connecting said first-stage cementing plug directly to said trip-plug;
(I) means defining a passage through each plug for the flow of cementing fluids from the longitudinal passage of the mandrel into the well casing string;
(J) said first-stage cementing plug having means cooper-ative with a first closure member in said cementing fluid to close the passage in said first-stage cementing plug and effect release of said third re-leasable means responsive to cementing fluid pressure to launch said first-stage cementing plug for travel down said casing string to close said firststage cementing port means;
(K) said trip-plug having means cooperative with a second closure member in said cementing fluid to close the passage in said trip-plug to effect release of said second releasable means responsive to cementing fluid pressure to launch said trip-plug for travel down said casing string to open said second-stage cementing port means; and (L) said shut-off plug having means cooperative with a third closure member in said cementing fluid to close the passage in said shut-off plug and effect re-lease of said first releasable means responsive to cementing fluid pressure to launch said shut-off plug for travel down said casing string to close said second-stage cementing port means.
2. A subsea well installation according to claim 1 comprising check valve means for preventing flow of liquid through said first-stage cementing port menas from the exter-ior of said composite string of casing to the interior thereof.
3. A subsea well installation according to claim 1, where-in said releasable means comprises shear pin means.
4. A subsea well installation according to claim 1, wherein said shut-off plug and said first-stage cementing plug each comprises flexible, annular wiper means extending outwardly therefrom into wiping engagement with the bore of said composite string of casing, and said trip-plug has a smaller diameter than said composite string of casing and is adapted to gravitate through cementing fluid in said string of casing.
5. A subsea well installation according to claim 4, wherein said trip-plug has longitudinal groove means spaced circumferentially about its exterior.
6. A subsea well installation according to claim 1, com-prising surge chamber means surrounding said mandrel and fluid port means communicating said surge chamber means with the longitudinal passage of said tubular mandrel.
7. A subsea well installation according to claim 1, including swivel means in said tubular mandrel.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA324,427A CA1062148A (en) | 1976-05-10 | 1979-03-29 | Subsea well installation |
Applications Claiming Priority (3)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US05/684,808 US4042014A (en) | 1976-05-10 | 1976-05-10 | Multiple stage cementing of well casing in subsea wells |
| CA276,937A CA1060781A (en) | 1976-05-10 | 1977-04-26 | Multiple stage cementing of well casing in subsea wells |
| CA324,427A CA1062148A (en) | 1976-05-10 | 1979-03-29 | Subsea well installation |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA1062148A true CA1062148A (en) | 1979-09-11 |
Family
ID=27165045
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA324,427A Expired CA1062148A (en) | 1976-05-10 | 1979-03-29 | Subsea well installation |
Country Status (1)
| Country | Link |
|---|---|
| CA (1) | CA1062148A (en) |
-
1979
- 1979-03-29 CA CA324,427A patent/CA1062148A/en not_active Expired
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