Patent Grant
RE44520
The present invention relates to a flow completion apparatus for producing oil or gas from a subsea well. More particularly, the invention relates to a flow completion apparatus which comprises a tubing hanger having an annulus bore which is adapted to communicate with a choke and kill line of a blowout preventer which is installed over the tubing hanger during installation and workover of the flow completion apparatus.
Flow completion assemblies for producing oil or gas from subsea wells may generally be categorized as either conventional or horizontal. A typical horizontal flow completion assembly is disclosed in U.S. Pat. No. 6,039,119, hereby incorporated herein by reference.
International Publication No. WO 01/73259 of International Application No. PCT/US01/09607 filed Mar. 22, 2001 and published Oct. 4, 2001, shows a tubing hanger with an annulus bore. International Publication No. WO 01/73259 is hereby incorporated herein by reference.
The flow completion apparatus comprises a wellhead housing which is installed at the upper end of the wellbore; a tubing spool which is connected over the wellhead housing and which includes a central bore which extends axially therethrough, a production outlet which communicates with the central bore, and an annulus passageway which communicates with the tubing annulus; a tubing hanger which is supported in the central bore and is connected to an upper end of the tubing string, the tubing hanger including a production bore which extends axially therethrough and a production passageway which communicates between the production bore and the production outlet; a first closure member which is positioned in the production bore above the production passageway; production seals positioned between the tubing hanger and central bore above and below the production passageway; and a tubing annulus seal which is positioned between the tubing hanger and the central bore below the production passageway and production seals. Furthermore, the tubing spool also comprises a workover passageway which extends between the annulus passageway and a portion of the central bore that is located between the production seals and the tubing annulus seal, and the tubing hanger also comprises an annulus bore which extends between the workover passageway and the upper end of the tubing hanger. In this manner, fluid communication between the tubing annulus and the upper end of the tubing hanger may be established through the annulus passageway, the workover passageway, and the annulus bore.
The flow completion apparatus further comprises a blowout preventer which is removably connectable to the top of the tubing spool and which includes a BOP bore, at least one set of BOP rams, and at least one choke and kill line that communicates with a portion of the BOP bore which is located below the BOP rams; and a tubing hanger running tool which is removably connectable to the top of the tubing hanger and which includes a generally cylindrical outer diameter surface and a production port that communicates with the production bore in the tubing hanger. An annulus passageway extends between the annulus bore in the tubing hanger and the BOP choke and kill line. This passageway may either be the annular area around the tubing hanger running tool or may include an annulus port through the running tool that communicates between the annulus bore and an opening which is formed in the outer diameter surface of the tubing hanger running tool to communicate with the BOP choke and kill line. In this manner, fluid communication between the tubing annulus and the BOP choke and kill line may be established through the annulus passageway, the workover passageway, the annulus bore, either the annular area around the tubing hanger running tool or an annulus port in the tubing hanger running tool, and the portion of the BOP bore which is located below the closed BOP ram.
The annulus bore in the tubing hanger provides a convenient means for connecting the tubing annulus with the BOP choke and kill line. An annulus port in the tubing hanger running tool provides a closed path between the annulus bore in the tubing hanger and the BOP choke and kill line.
A first barrier between the wellbore and the environment is provided by both the first closure member in the production bore and the tubing annulus seal between the tubing hanger and the tubing spool. In addition, a second barrier between the wellbore and the environment is provided by both a second closure member that is positioned in the production bore above the first closure member and the production seals that are positioned between the tubing hanger and the tubing spool above the tubing annulus seal. In this manner, both the first and second barriers between the wellbore and the environment are mounted in or on the tubing hanger.
These and other objects and advantages of the present invention will be made apparent from the following detailed description, with reference to the accompanying drawings. In the drawings, the same reference numerals are used to denote similar components in the various embodiments.
The present invention relates to methods and apparatus for flow completion and particularly for circulation in the borehole of a well during installation and workover. The present invention is susceptible to embodiments of different forms. There are shown in the drawings, and herein will be described in detail, specific embodiments of the present invention with the understanding that the present disclosure is to be considered an exemplification of the principles of the invention, and is not intended to limit the invention to that illustrated and described herein.
In particular, various embodiments of the present invention provide a number of different constructions and methods of operation of the completion system. The embodiments of the present invention also provide a plurality of methods for circulation in the borehole of a well. It is to be fully recognized that the different teachings of the embodiments discussed below may be employed separately or in any suitable combination to produce desired results. Reference to up or down will be made for purposes of description with up meaning away from the bottom of the well and down meaning toward the bottom of the well.
In the description which follows, the use of the same reference numerals throughout the specification and drawings indicates like parts. The drawing figures are not necessarily to scale. Certain features of the invention may be shown in exaggerated in scale or in somewhat schematic form and some details of conventional elements may not be shown in the interest of clarity and conciseness.
Referring initially to
The tubing hanger 18 also includes an annulus bore 80 which extends between the upper end and lower end of the tubing hanger 18. In this manner, communication between the tubing annulus 24 and area 86 above the upper end of tubing hanger 18 is provided by the annulus passageway 32, the workover passageway 36, and the annulus bore 80. This arrangement permits communication between the tubing annulus 24 and area 86 and also a choke and kill line in a BOP with tree cap 20 removed as shown in
The flow completion apparatus 10 may also comprise a production master valve 44 and a production wing valve 46 to control flow through the production outlet 30, and an annulus master valve 48, an annulus wing valve 50 and a workover valve 52 to control flow through the annulus passageway 32, the annulus outlet 34 and the workover passageway 36, respectively. While these valves may be any suitable closure members, they are preferably remotely operated gate valves. Moreover, some or all of the valves may be incorporated into the body of the tubing spool 14, into separate valve blocks which are bolted onto the tubing spool, or into individual valve assemblies which are connected to their respective outlets or passageways in the tubing spool with separate lengths of conduit. Furthermore, the production outlet 30 and the annulus outlet 34 are preferably connected to respective flow loops which communicate with a surface vessel, either directly or via a manifold, in a manner that is well known in the art.
In the production mode of operation of the flow completion apparatus 10, shown in
Referring now to
During both installation and workover of the flow completion assembly 10, communication between the tubing annulus 24 and the surface vessel may be established through the annulus passageway 32, the workover passageway 36, the annulus bore 80, the central bore 16, the BOP bore 64, and the choke and kill line 68. For example, deep well circulation can be accomplished by pumping fluid down the tubing hanger running tool bore 70, through the production bore 26, through the flowbore of tubing string 22, around or through the lower end of the tubing string 22, up the tubing annulus 24, through the annulus passageway 32, through the workover passageway 36, through the annulus bore 80, into the central bore 16 above the tubing hanger 18, into the BOP bore 64 and through the BOP choke and kill line 68 to the surface.
Referring now to
Referring now to
The tubing hanger 118 also includes an annulus bore 140 which extends between the top and the lower outer diameter of the tubing hanger 118, and the tubing spool 114 comprises a workover passageway 142 that extends between the annulus passageway 130 and the annulus bore 140. The communication between the workover passageway 142 and the tubing annulus 122 is sealed by tubing annulus seal ring 157. In this manner, communication between the tubing annulus 122 and the top of tubing hanger 118 is provided by the annulus passageway 130, the workover passageway 142, and the annulus bore 140. This arrangement permits communication between the tubing annulus 122 and a BOP to be routed through a tubing hanger running tool, shown in
The flow completion apparatus 110 may also comprises a production master valve 144 and a production wing valve 146 to control flow through the production outlet 128, and an annulus master valve 148, an annulus wing valve 150 and a workover valve 152 to control flow through the annulus passageway 130, the annulus outlet 132 and the workover passageway 142, respectively. While these valves may be any suitable closure members, they are preferably remotely operated gate valves. Moreover, some or all of the valves may be incorporated into the body of the tubing spool 114, into separate valve blocks which are bolted onto the tubing spool, or into individual valve assemblies which are connected to their respective outlets or passageways in the tubing spool with separate lengths of conduit. Furthermore, the production outlet 128 and the annulus outlet 132 are preferably connected to respective flow loops which communicate with a surface vessel, either directly or via a manifold, in a manner that is well known in the art.
In the production mode of operation of the flow completion apparatus 110, shown in
In accordance with the present invention, a first barrier between the well bore and the environment is provided by the closure member 138 and the production seals 134, 136, which together serve to isolate the fluid in the production bore from the environment above and below the tubing hanger 118. A second barrier between the well bore and the environment is provided by a suitable second closure member 154, which is mounted in the production bore 124 above the closure member 138, and secondary seal 156 and tubing annulus seal 157, preferably a metal ring seals, which are mounted on the tubing hanger 118 above and below production passageway 126. Thus, the necessary first and second barriers for isolating the production passageway 126 from the environment are provided by components which are mounted on or in the tubing hanger 118.
The present invention also provides for isolating the tubing annulus 122 from the environment above the tubing hanger 118 during the production mode of operation. Provided the annular master valve 148 and the workover valve 152 are closed, the production seals 134, 136, the secondary seal 156, and the tubing annulus seal 157 will provide the required first and second barriers between the tubing annulus and the environment. However, when pressure in the tubing annulus 122 needs to be bled off through the annulus passageway 130 and the annulus outlet 132, or when gas is introduced into the tubing annulus through the annulus outlet and the annulus passageway during gas lift applications, the annulus master valve 148 must be opened.
Therefore, the flow completion apparatus preferably also comprises a tree cap 158 which includes an annulus stab 160 that seals into the top of the annulus bore 140 to provide a second barrier, in conjunction with the workover valve 152, between the tubing annulus 122 and the environment when the environment master valve 148 is open. While the tree cap 158 may include an annular, preferably non-metallic seal (not shown) to seal against the tubing spool 114 and thereby prevent sea water from entering the central bore 116, the tree cap is not intended to provide a barrier against well pressure in the production bore. The tree cap 158 is preferably landed on the tubing hanger 118 and locked to the tubing spool 114 with a convention lockdown mechanism 162. This lockdown mechanism will provide a backup to the lockdown mechanism used to secure the tubing hanger to the running tool. It should be noted that, although the tree cap 158 is depicted as an internal tree cap, it could instead be configured as an external tree cap.
Referring now to
Thus, with the BOP rams 170, 172 sealed against the tubing hanger running tool 174, communication between the tubing annulus 122 and the BOP choke and kill line 168 may be established through the annulus passageway 130, the workover passageway 142, the annulus bore 140, the annulus port 180, and the portion 167 of the BOP bore 166 which is located between the BOP rams 170, 172. For example, with the annulus wing valve 150 closed, pressure can be transmitted from the surface vessel down the choke and kill line 168, through the annulus portion 180, through the tubing hanger annulus bore 140, through the workover passageway 142, through the annulus passageway 130, and into the tubing annulus 122. The well circulation may be accomplished by closing both the annulus wing valve 150 and the production master valve 144 and pumping fluid down the choke and kill line 168 through the annulus port 180, through the annulus bore 140, through the workover passageway 142, through the annulus passageway 130, down the tubing annulus 122, past the downhole packer, up the tubing string 120, through the production bore 124, and up the production port 176. Moreover, since the flow between the tubing hanger annulus bore 140 and the choke and kill line 168 is restricted by the tubing hanger running tool 174, no possibility exists that the flow will foul the tubing hanger lockdown mechanism or erode the central bore 116.
Referring now to
Referring now to
The tubing hanger 118 also includes an annulus bore 140 which extends between the top and the outer diameter of the tubing hanger 118, and the tubing spool 114 comprises a workover passageway 142 that extends between the annulus passageway 130 and the annulus bore 140. The communication between the workover passageway 142 and the tubing annulus 122 is sealed by an annular seal ring 157. Tubing hanger 118 also includes an annulus bypass bore 141 extending from annulus bore 140 through valve 139 and continuing through bypass bore 143 to production bore 124. In this manner fluid communication between the tubing annulus 122 and the production bore 124 above closure member 138 is provided.
Referring now to
Similar valve actuation member 151 and valve stem 153 are shown as an alternate for valve closure member 154. The valve actuation member 151 attached to tubing spool 114 may be used outside or inside the necessary second barriers for isolating the production bore 124 from the environment as described earlier.
The flow completion apparatus 110 may also comprise a production master valve 144 and a production wing valve 146 to control flow through the production outlet 128, and an annulus master valve 148, an annulus wing valve 150 and a workover valve 152 to control flow through the annulus passageway 130, the annulus outlet 132 and the workover passageway 142, respectively. While these valves may be any suitable closure members, they are preferably remotely operated gate valves. Moreover, some or all of the valves may be incorporated into the body of the tubing spool 114, into separate valve blocks which are bolted onto the tubing spool, or into individual valve assemblies which are connected to their respective outlets or passageways in the tubing spool with separate lengths of conduit. Furthermore, the production outlet 128 and the annulus outlet 132 are preferably connected to respective flow loops which communicate with a surface vessel, either directly or via a manifold, in a manner that is well known in the art.
In the production mode of operation of the flow completion apparatus 110, shown in
In accordance with the present invention, a first barrier between the well bore and the environment is provided by the closure member 138 and the production seals 134, 136, which together serve to isolate the fluid in the production bore from the environment above and below the tubing hanger 118. A second barrier between the well bore and the environment is provided by a suitable second closure member 154, which is mounted in the production bore 124 above the closure member 138, and secondary seal 156 and tubing annulus seal 157, preferably a metal ring seals, which are mounted on the tubing hanger 118 above and below production passageway 126. Thus, the necessary first and second barriers for isolating the production passageway 126 from the environment are provided by components which are mounted on or in the tubing hanger 118.
The present invention also provides for isolating the tubing annulus 122 from the environment above the tubing hanger 118 during the production mode of operation. Provided the annular master valve 148 and the workover valve 152 are closed, the production seals 134, 136, the secondary seal 156, and the tubing annulus seal 157 will provide the required first and second barriers between the tubing annulus and the environment. However, when pressure in the tubing annulus 122 needs to be bled off through the annulus passageway 130 and the annulus outlet 132, or when gas is introduced into the tubing annulus through the annulus outlet and the annulus passageway during gas lift applications, the annulus master valve 148 must be opened.
Therefore, the flow completion apparatus preferably also comprises a tree cap 158 which includes an annulus stab 160 that seals into the top of the annulus bore 140 to provide a second barrier, in conjunction with the workover valve 152, between the tubing annulus 122 and the environment when the environment master valve 148 is open. While the tree cap 158 may include an annular, preferably non-metallic seal (not shown) to seal against the tubing spool 114 and thereby prevent sea water from entering the central bore 116, the tree cap is not intended to provide a barrier against well pressure in the production bore. The tree cap 158 is preferably landed on the tubing hanger 118 and locked to the tubing spool 114 with a convention lockdown mechanism 162. This lockdown mechanism will provide a backup to the lockdown mechanism used to secure the tubing hanger to the running tool. It should be noted that, although the tree cap 158 is depicted as an internal tree cap, it could instead be configured as an external tree cap.
Referring now to
In a similar manner as described for
The flow completion apparatus 210 may also comprise a production master valve 244 and a production wing valve 246 to control flow through the production outlet 230, and an annulus master valve 248, an annulus wing valve 250 and a workover valve 252 to control flow through the annulus passageway 232, the annulus outlet 234 and the workover passageway 236, respectively. While these valves may be any suitable closure members, they are preferably remotely operated gate valves. Moreover, some or all of the valves may be incorporated into the body of the tubing spool 214, into separate valve blocks which are bolted onto the tubing spool, or into individual valve assemblies which are connected to their respective outlets or passageways in the tubing spool with separate lengths of conduit. Furthermore, the production outlet 230 and the annulus outlet 234 are preferably connected to respective flow loops which communicate with a surface vessel, either directly or via a manifold, in a manner that is well known in the art. See U.S. Pat. No. 5,372,199, hereby incorporated herein by reference.
In the production mode of operation of the flow completion apparatus 210, shown in
The embodiments described above assume a requirement for double barriers. It should be appreciated that one of the barriers may be eliminated should only one barrier be required in a particular jurisdiction.
It should be recognized that, while the present invention has been described in relation to the preferred embodiments thereof, those skilled in the art may develop a wide variation of structural and operational details without departing from the principals of the invention. For example, the various elements shown in the different embodiments may be combined in a manner not illustrated above. Therefore, the appended claims are to be construed to cover all equivalents falling within the true scope and spirit of the invention.
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| Number | Date | Country |
|---|---|---|
| 2192921 | Jan 1988 | GB |
| WO 0047864 | Aug 2000 | WO |
| WO 0173254 | Oct 2001 | WO |
| WO 0173256 | Oct 2001 | WO |
| WO 0173259 | Oct 2001 | WO |
| WO 0173260 | Oct 2001 | WO |
| Entry |
|---|
| SPE 23145; Sanders, R.O., Installation of Concentric Subsea Completions From a Jack-Up in the Welland Field: A Case History, Society of Petroleum Engineers, Inc., 1981, pp. 405-415. |
| SPE 13976 D.S. Huber, G.F. Simmers and C.S. Johnson; Through Bore Subsea Christmas Trees; Sep. 1985; (p. 15). |
| Design Certification Manuals FOR Phillips North Hewett Subsea Completion Well 48/30-10; Jul. 29, 1986; (p. 3). |
| National Supply Company (UK) Limited; Through Bore Tree System and Workover Riser 7 1/16″ 5000 psi; Jun. 1985; (pp. KD092771-KD092815). |
| National Supply Company (UK) Limited; Through Bore Tree Syustem and Workover Riser 7 1/16″-5M; Oct. 1985; (pp. KD092816-KD092837). |
| National Oilwell (UK) Limited; Through Bore Tree System; Jan. 1993; St. Magnus House; (p. 24). |
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| Welland Subsea Tree; Figure 8; (1 sheet) undated. |
| Number | Date | Country | |
|---|---|---|---|
| Parent | 10008104 | Nov 2001 | US |
| Child | 11297819 | US |
