Patent Grant
9534474
This invention relates in general to subsea well production, and in particular to a connection system for connecting flow interface equipment, such as a pump to a subsea Christmas tree assembly.
A subsea production facility typically comprises a subsea Christmas tree with associated equipment. The subsea Christmas tree typically comprises a choke located in a choke body in a production wing branch. There may also be a further choke located in an annulus wing branch. Typically, well fluids leave the tree via the production choke and the production wing branch into an outlet flowline of the well. However, in such typical trees, the fluids leave the well unboosted and unprocessed.
According to a first aspect of the present invention there is provided an apparatus for connecting to a subsea wellbore, the wellbore having a manifold and a choke body, the apparatus comprising: a frame adapted to land on the manifold; a conduit system having a first end for connection to the interior of the choke body and a second end for connection to a processing apparatus; wherein the conduit system comprises a conduit means supported by the frame; wherein the frame comprises at least one frame member that is adapted to land on the manifold in a first stage of the connection and wherein the conduit means is adapted to be brought into fluid communication with the interior of the choke body in a second stage of the connection.
The two-stage connection provides the advantage that damage to the mating surfaces between the conduit means and the flow line of the tree assembly can be avoided whilst the frame is being landed, since at least a part of the frame is landed before the connection between the conduit means and the interior of the choke body is made up. Hence, the two-stage connection acts to buffer and protect the mating surfaces. The two-stage connection also protects the choke itself from damage whilst the frame is being landed; in particular, the mating surface of the choke is protected.
In some embodiments, processing apparatus e.g. multi-phase flow meters and pumps can be mounted on the frame and can be landed on the tree with the frame. Alternatively, the processing apparatus may be located remote from the tree, e.g. on a further subsea installation such as a manifold or a pile, and the frame may comprise connections for jumper conduits which can lead fluids to and from the remote processing apparatus.
The processing apparatus allows well fluids to be processed (e.g. pressure boosted/injected with chemicals) at the wellhead before being delivered to the outlet flowline of the well. The invention may alternatively be used to inject fluids into the well using the outlet flowline as an inlet.
Often the processing apparatus, e.g. subsea pump, is flow meter, etc. is quite heavy and bulky. In embodiments where heavy/bulky apparatus is carried by the frame, the risk of damage to the mating surfaces between the conduit means and the flow line of the tree assembly is particularly great.
Optionally, the apparatus further comprises an actuating means mounted on the frame, the actuating means being adapted to bring the conduit means into fluid communication with the interior of the choke body. Typically, the actuating means comprises at least one hydraulic cylinder. Alternatively, the actuating means may comprise a cable or a screw jack which connects the conduit means to the frame, to control the movement of the conduit means relative to the frame.
The conduit means is not necessarily brought into direct communication with the choke body. In some embodiments (the first embodiment and the third embodiment below), the conduit means is connected with the interior of the choke body via a further, secondary conduit.
In a first embodiment, a mounting apparatus is provided for landing a flow interface device, particularly a subsea pump or compressor (referred to collectively at times as “pressure intensifier”) on a subsea production assembly.
Optionally, the at least one frame member of the first connection stage comprises a lower frame member, and the apparatus further comprises an upper frame member, the upper frame member and the lower frame member having co-operating engagement means for landing the upper frame member on the lower frame member.
In the first embodiment, a secondary conduit in the form of a mandrel with a flow passage is mounted to the lower frame member. The operator lowers the lower frame member into the sea and onto the production assembly. The production assembly has an upward facing receptacle that is sealingly engaged by the mandrel.
In this embodiment, the conduit means comprises a manifold, which is mounted to the upper frame member. The manifold is connected to a flow interface device such as a pressure intensifier, which is also mounted to the upper frame member. The operator lowers the upper frame member along with the manifold and pressure intensifier into the sea and onto the lower frame member, landing the manifold on the mandrel. During operation, fluid flows from the pressure intensifier through the manifold, the mandrel, and into the flow line.
Preferably, the subsea production assembly comprises a Christmas tree with a frame having guide posts. The operator installs extensions to the guide posts, if necessary, and attaches guidelines that extend to a surface platform. The lower and upper frame members have sockets with passages for the guidelines. The engagement of the sockets with the guide posts provides gross alignment as the upper and lower frame members are lowered onto the tree frame.
Also, preferably the Christmas tree frame has upward facing guide members that mate with downward facing guide members on the lower frame member for providing finer alignment. Further, the lower frame member preferably has upward facing guide members that mate with downward facing guide members on the upper frame member for providing finer alignment. One or more locking members on the lower frame member lock the lower frame member to the tree frame. Additionally, one or more locking members on the upper frame member lock the upper frame member to the lower frame member.
Optionally, the apparatus further comprises buffering means provided on the frame, the buffering means providing a minimum distance between the frame and the tree.
The buffering means may comprise stops or adjustable mechanisms, which may be incorporated with the locking members, or which may be separate from the locking members.
The adjustable stops define minimum distances between the lower frame member and the upper plate of the tree frame and between the lower frame member and the upper frame member.
The buffering means typically comprise threaded bolts, which engage in corresponding apertures in the frame, and which can be rotated to increase the length they project from the frame. The ends of the threaded bolts typically contact the upper frame member of the tree, defining a minimum distance between the frame and the tree.
Optionally, a further buffering means is provided between the lower and upper frame members to define a minimum distance between the lower and upper frame members. The further buffering means also typically comprises threaded bolts which extend between the lower and upper frame members. The extent of projection of the threaded bolts can be adjusted to provide a required separation of the upper and lower frame members.
The buffering means (e.g. the adjustable stops) provides structural load paths from the upper frame member through the lower frame member and tree frame to the tree and the wellhead on which the tree is mounted. These load paths avoid structural loads passing through the mandrel to the upward facing receptacle (i.e. the choke body).
In a second embodiment, the frame is lowered as a unit, but typically has an upper portion (an upper frame member) that is vertically movable relative to the lower portion (a lower frame member). A processing apparatus (in the form of a pressure intensifier) and a conduit means (a mandrel) are mounted to the upper portion. An actuating means comprising one or more jack mechanisms is provided between the lower and upper portions of the frame. When the lower portion of the frame lands on the tree frame, the lower end of the mandrel will be spaced above the flow line receptacle. The jack mechanisms then lower the upper portion of the frame, causing the mandrel to stab sealingly into the receptacle (the choke body). Thus, in this embodiment, the conduit means comprises a single mandrel having a single flowpath therethrough.
In a third embodiment, the conduit means has a flexible portion. Preferably, the flexible portion is moveable relative to the frame. Typically, the flexible portion of the conduit means is fixed relative to the frame at a single point. Typically, the flexible portion of the conduit means is connected to the processing apparatus and supported at the processing apparatus connection, in embodiments where the processing apparatus is supported on the frame.
Optionally, the conduit means comprises two conduits, one of which is adapted to carry fluids going towards the processing apparatus, the other adapted to carry fluids returning from the processing apparatus. Typically, each of the two conduits of the conduit means is fixed relative to the frame at a respective point. Typically, the flexible portion of each of the two conduits of the conduit means is connected to the processing apparatus and is supported at the processing apparatus connection (where a processing apparatus is provided on the frame).
Typically, the flexible portion of the conduit means is resilient. Typically, the direction of movement of the flexible portion of the conduit means in the second stage of the connection defines an axis of connection and the flexible portion of the conduit means is curved in a plane perpendicular to the axis of connection to provide resilience in the connection direction. In such embodiments, the flexible portion of the conduit means is in the form of a coil, or part of a coil. This allows the lower end of the conduit means (the connection end) to be moved resiliently in the connection direction.
Typically, the flexible portion of the conduit means supports a connector adapted to attach to the choke body (either directly or via a further conduit extending from the choke body), the flexible portion of the conduit means allowing relative movement of the connector and the frame to buffer the connection.
Typically, an actuating means is provided which is adapted to move the flexible portion relative to the frame to bring an end of the flexible portion into fluid communication with the interior of the choke body. The actuating means typically comprises a swivel eye mounting hydraulic cylinder.
Considering now all embodiments of the invention, the conduit system may optionally provide a single flowpath between the choke body and the processing apparatus.
Alternatively, the conduit system provides a two-flowpath system: a first flowpath from the choke body to the processing apparatus and a second flowpath from the processing apparatus to the choke body. In such embodiments, the conduit system can comprise a housing and an inner hollow cylindrical member, the inner cylindrical member being adapted to seal within the interior of the choke body to define a first flow region through the bore of the cylindrical member and a second separate flow region in the annulus between the cylindrical member and the housing.
Typically, the first and second flow regions are adapted to connect to a respective inlet and an outlet of the processing apparatus.
Such embodiments can be used to recover fluids from the well via a first flowpath, process these using the processing apparatus (e.g. pressure boosting) and then to return the fluids to the choke body via a second flowpath for recovery through the production wing branch. The division of the inside of the choke body into first and second flow regions by the inner cylindrical member allows separation of the first and second flowpaths within the choke body.
If used, the housing and the inner hollow cylindrical member typically are provided as the part of the conduit system that directly connects to the choke body, i.e. in the first embodiment, this is the secondary conduit; in the second embodiment, the conduit means, and in the third embodiment, the secondary conduit.
Optionally, the processing apparatus is provided on the frame. In this case, the processing apparatus is typically connected to the conduit means before the frame is landed on the tree.
Alternatively, the processing apparatus is provided on a further subsea manifold, such as a suction pile. Jumper cables can be connected between the frame on the manifold and the further subsea manifold to connect the processing apparatus to the conduit system. In this case, the processing apparatus is typically connected to the conduit means as a final step.
In all embodiments, the frame typically includes guide means that co-operate with guide means provided on the manifold, to align the frame with the manifold. The frame may also or instead comprise a guide pipe that surrounds at least a part of the conduit system, to protect it from impact damage.
All embodiments use the space inside the choke body after the choke bonnet has been removed and the choke withdrawn. However, it may still be desirable to be able to use a choke to control the fluid flow. Optionally, a replacement choke is provided on the frame, the replacement choke being connectable to the conduit system.
Embodiments of the invention can be used for both recovery of production fluids and injection of fluids.
According to a second aspect of the present invention there is provided a method of connecting a processing apparatus to a subsea wellbore, the wellbore having a manifold and a choke body, the method comprising: landing a frame on the manifold and connecting a conduit system between the choke body and the processing apparatus, the frame supporting a conduit means of the conduit system; wherein the frame comprises at least one frame member that is landed on the manifold in a first connection stage, and wherein the conduit means is brought into fluid communication with the interior of the choke body in a second connection stage.
The method typically includes the initial steps of removing the choke bonnet and connecting the secondary conduit to interior of the choke body.
The choke bonnet is removed and the secondary conduit may be installed by choke bonnet changing equipment (e.g. the third embodiment). Alternatively, the secondary conduit may be supported on the lower frame member and may be installed when the lower frame member is landed on the manifold (e.g. the first embodiment).
According to a third aspect of the present invention there is provided an apparatus for connecting to a subsea wellbore, the wellbore having a manifold and a choke body, the apparatus comprising: a frame having a conduit system, the frame being adapted to land on the tree, the conduit system including a first end which is adapted to connect to the choke body such that the conduit is in fluid communication with the interior of the choke body, and a second end connectable to a processing apparatus; wherein the frame comprises buffering means adapted to buffer the connection between the first end of the conduit system and the choke body.
In the first embodiment, the buffering means may be provided by the adjustable stop means, which provide structural load paths from the upper frame member through the lower frame member and tree frame to the tree and the wellhead on which the tree is mounted which avoid structural loads passing through the mandrel to the choke body.
In the second embodiment, the buffering means is typically provided by the arrangement of the upper and lower frame members, the upper frame member being moveable to lower the mandrel (the conduit means) into connection with the choke body in a controlled manner, only after the frame has been landed.
In the third embodiment, the buffering means may be provided by the flexible portion of the conduit means, which allows movement of the conduit end that connects to the secondary conduit. Therefore, the connection end of the conduit means will not heavily impact into the secondary conduit as it is able to deflect as necessary, using the flexibility of the conduit means, and can optionally be maneuvered for even greater control (e.g. by an actuating mechanism).
According to a fourth aspect of the present invention there is provided an apparatus for connecting to a subsea wellbore, the wellbore having a manifold and a choke body, the apparatus comprising: a frame adapted to land on the manifold; a conduit system having a first end for connection to the choke body and a second end for connection to a processing apparatus; wherein at least a part of the conduit system is supported by the frame; wherein the conduit system comprises at least one flexible conduit having an end that is moveable relative to the frame to make up a communication between the processing apparatus and the choke body. In such embodiments, the end of the flexible conduit can deflect if it impacts with the choke body (or any secondary conduit extending from the choke body). Thus in such embodiments, the flexible conduit ensures that the load carried by the frame is not transferred to the choke body.
Embodiments of the invention will now be described, by way of example only, and with reference to the following drawings, in which:
Referring to
A production choke body or receptacle 23 mounts to production wing valve 21. Choke body 23 comprises a housing for a choke insert (not shown) that is adjustable to create a back pressure and a desired flow rate. Choke body 23 connects to a production flow line 25 that leads to sea floor processing equipment or directly to a production facility at sea level. After being installed with a pressure intensifier, as will be subsequently explained, a choke insert may not be required. One use for the connecting apparatus of this invention is to retrofit existing trees that have previously operated without a pressure intensifier.
Tree 13 may also have an annulus valve 27 that communicates with a tubing annulus passage (not shown) in the well. An annulus choke 29 connects to annulus valve 27 for controlling a flow rate either into or out of the tubing annulus. Annulus choke 29 is normally located on a side of production assembly 11 opposite production choke body 23. Annulus choke 29 has a body with a choke insert similar to production choke body 23.
A tree cap 31 releasably mounts to the upper end of tree 13. A tree frame 33 extends around tree 13 for mounting various associated equipment and providing protection to tree 13 if snagged by fishing nets. Tree frame 33 is structurally connected to the body of tree 13, such that weight imposed on tree frame 33 transfers to tree 13 and from there to the wellhead housing (not shown) on which tree 13 is mounted. Tree frame 33 has an upper frame member portion or plate 35 that in this instance is located above swab valve 19 and below tree cap 31. Upper plate 35 surrounds tree 13, as shown in
As shown in
Still referring to
A clamp 51 locks flange 49 to the flange of choke body 23. Clamp 51 is preferably the same apparatus that previously clamped the choke insert (not shown) into choke body 23 when production assembly 11 was being operated without a pressure intensifier. Clamp 51 is preferably actuated with an ROV (remote operated vehicle) to release and actuate clamp 51.
Referring to
Referring to
Lower frame member 45 also has guide post sockets 71, each preferably being a hollow tube with a downward facing funnel on its lower end. Guide post sockets 71 slide over guide lines 43 (
Referring still to
An adjustment mechanism or mechanisms (not shown) may extend between lower frame member 45 and tree frame upper plate 37 to assure that the weight on lower frame member 45 transfers to tree frame upper plate 37 and not through mandrel 47 to choke body 23. While the lower end of mandrel 47 does abut the upper end of choke body 23, preferably, very little if any downward load due to any weight on lower frame member 45 passes down mandrel 47 to choke body 23. Applying a heavy load to choke body 23 could create excessive bending moments on the connection of production wing valve 21 to the body of tree 13. The adjustment mechanisms may comprise adjustable stops on the lower side of lower frame member 45 that contact the upper side of tree frame upper plate 37 to provide a desired minimum distance between lower frame member 45 and upper plate 37. The minimum distance would assure that the weight on lower frame member 45 transfers to tree upper plate 35, and from there through tree frame 33 to tree 13 and the wellhead housing on which tree 13 is supported. The adjustment mechanisms could be separate from locking devices 69 or incorporated with them.
Referring to
As shown by the dotted lines, a motor 95, preferably electrical, is mounted on upper frame member 81. A filter 97 is located within an intake line 98 of a subsea pump 99. Motor 95 drives pump 99, and the intake in this example is in communication with sea water. Pump 99 has an outlet line 101 that leads to passage 93 of manifold 91.
As shown in
Adjustable mechanisms or stops (not shown) may also extend between lower frame member 45 and upper frame member 81 to provide a minimum distance between them when landed. The minimum distance is selected to prevent the weight of pump 99 and motor 95 from transmitting through mandrel connector 83 to mandrel 47 and choke body 23. Rather, the load path for the weight is from upper frame member 81 through lower frame member 45 and tree frame upper plate 35 to tree 13 and the wellhead housing on which it is supported. The load path for the weight on upper frame member 81 does not pass to choke body 23 or through guide posts 41. The adjustable stops could be separate from locking devices 107 or incorporated with them.
In the operation of this example, production assembly 11 may have been operating for some time either as a producing well, or an injection well with fluid delivered from a pump at a sea level platform. Also, production assembly 11 could be a new installation. Lower frame member 45, upper frame member 81 and the associated equipment would originally not be located on production assembly 11. If production assembly 11 were formerly a producing well, a choke insert (not shown) would have been installed within choke body 23.
To install pressure intensifier 99, the operator would attach guide post extensions 42, if necessary, and extend guidelines 43 to the surface vessel or platform. The operator removes the choke insert in a conventional manner by a choke retrieval tool (not shown) that interfaces with the two sets of guide members 37 adjacent cutout 36 (
The operator then lowers lower frame member 45 along guidelines 43 and over guide posts 41. While landing, guide members 67 and lock members 69 (
The operator then lowers upper frame member 81, including pump 99, which has been installed at the surface on upper frame member 81. Upper frame member 81 slides down guidelines 43 and over guide posts 41 or their extensions 42. After manifold 91 engages mandrel 47, connector 83 is actuated to lock manifold 91 to mandrel 47. Electrical power for pump motor 95 may be provided by an electrical wet-mate connector (not shown) that engages a portion of the control pod (not shown), or in some other manner. If the control pod did not have such a wet mate connector, it could be retrieved to the surface and provided with one.
Once installed, with valves 17 and 21 open, sea water is pumped by pump 99 through outlet line 101, and flow passages 93, 52 (
An alternate embodiment is shown in
Mandrel 117 is rigidly mounted to upper frame member 113 in this embodiment and has a manifold portion on its upper end that connects to outlet line 101, which in turn leads from pressure intensifier or pump 99. Mandrel 117 is positioned over or within a hole 118 in lower frame member 111. When upper frame member 113 moves to the lower position, shown in
In the operation of the second embodiment, pressure intensifier 99 is mounted to upper frame member 113, and upper and lower frame members 113, 111 are lowered as a unit. Hydraulic cylinders 115 will support upper frame member 113 in the upper position. Guidelines 43 and guide posts 41 guide the assembly onto tree frame upper plate 35, as shown in
Located at approximately the four corners of the frame 220 are guide funnels 230 attached to the base of the frame 220 on arms 228. The guide funnels 230 are adapted to receive the guide legs 210 to provide a first (relatively course) alignment means. The frame 220 is also provided with four “John Brown” legs 232, which extend vertically downwards from the base of the frame 220 so that they engage the John Brown feet 208 of the tree 200.
A processing apparatus in the form of a pump 234 is mounted on the frame 200. The pump 234 has an outlet and inlet, to which respective flexible conduits 236, 238 are attached. The flexible conduits 236, 238 curve in a plane parallel to the base of the frame 220, forming a partial loop that curves around the pump 234 (best shown in
A secondary conduit 250 is connected to the choke body 204, as best shown in
The upper portion of the secondary conduit 250 is solid (not shown in the cross-sectional view of
The inner member 254 is longer than the housing 252, and extends into the choke body 204 to a point below the production wing branch 202. The end of the inner member 254 is provided with a seal 259, which seals in the choke body 204 to prevent direct flow between the first and second flow regions. The secondary conduit 250 is clamped to the choke body 204 by a clamp 262 (see
Also shown in
The piping interface 240 is shown connected to the secondary conduit 250 in the views of
A method of connecting the pump 234 to the choke body 204 will now be described with reference to
The production wing valve is closed and the choke C is removed, as shown in
The landing stage of
In the second stage, the piping interface 240 is brought into engagement with the secondary conduit 250 and the clamp 260 is applied to fix the connection. The two-stage connection process provides protection of the mating surfaces of the secondary conduit 250 and the piping interface 240, and it also protects the choke 204; particularly the mating surface of the choke 204. Instead of landing the frame and connecting the piping interface 240 and secondary conduit in a single movement, which could damage the connection between the piping interface 240 and the secondary conduit 250 and which could also damage the choke 204, the two-stage connection facilitates a controlled, buffered connection.
The piping interface 240 being suspended on the curved flexible conduits 236, 238 allows the piping interface 240 to move in all three spatial dimensions; hence the flexible conduits 236, 238 provide a resilient suspension for the piping interface on the pump 234. If the piping interface 240 is not initially accurately aligned with the secondary conduit 250, the resilience of the flexible conduits 236, 238 allows the piping interface 240 to deflect laterally, instead of damaging the mating surfaces of the piping interface 240 and the secondary conduit 250. Hence, the flexible conduits 236, 238 provide a buffering means to protect the mating surfaces.
A slightly modified version of the third embodiment is shown in
However, in contrast with the
The replacement choke 324 is connected to one of the hubs 322 and to one of the flexible conduits 236, 238. The other of the flexible conduits 236, 238 is connected to the other hub 322.
The
In use, the well fluids flow through the choke body 240, through the annuli 258, 248, through flexible conduit 238 into one of the hubs 322, through a first jumper conduit, through the processing apparatus (e.g. a pump) through a second jumper conduit, through the other of the hubs 322, through the replacement choke 324, through the flexible conduit 236 through the bores 246, 256 and to the production wing outlet 206. Alternatively, the flow direction could be reversed to inject fluids into the well.
A further alternative embodiment is shown in
The principal difference between the embodiments of
To make up the connection between the piping interface 240 and the secondary conduit 250, the hydraulic cylinder is extended; the extended position is shown in
This invention has significant advantages. In the first embodiment, the lower frame member and mandrel are much lighter in weight and less bulky than the upper frame member and pump assembly. Consequently, it is easier to guide the mandrel into engagement with the choke body than it would be if the entire assembly were joined together and lowered as one unit. Once the lower frame member is installed, the upper frame member and pump assembly can be lowered with a lesser chance of damage to the subsea equipment. The upper end of the mandrel is rugged and strong enough to withstand accidental impact by the upper frame member. The two-step process thus makes installation much easier. The optional guide members further provide fine alignment to avoid damage to seating surfaces.
The movable upper and lower frame members of the mounting system of the second embodiment avoid damage to the seating surfaces of the mandrel and the receptacle.
While the invention has been shown in only a few of its forms, it should be apparent to those skilled in the art that it is not so limited but is susceptible to various changes without departing from the scope of the invention. For example, although shown in connection with a subsea tree assembly, the mounting apparatus could be installed on other subsea structures, such as a manifold or gathering assembly. Also, the flow interface device mounted to the upper frame member could be a compressor for compressing gas, a flow meter for measuring the flow rate of the subsea well, or some other device.
In the third embodiment, protection of the connection between the piping interface 240 and the secondary conduit 250 is achieved by the two-step connection process. Additional buffering is provided by the flexible conduits 236, 238, which allow resilient support of the piping interface 240 relative to the pump/the frame, allowing the piping interface 240 to move in all three dimensions. In some embodiments, even greater control and buffering are achieved using an actuation means to more precisely control the location of the piping interface 240 and its connection with the secondary conduit 250.
Improvements and modifications can be incorporated without departing from the scope of the invention. For example, it should be noted that the arrangement of the flowpaths in
Furthermore, in all embodiments, the flowpaths may be reversed, to allow both recovery and injection of fluids. In the third embodiment, the flow directions in the flexible conduits 236, 238 (and in the rest of the apparatus) would be reversed.
A replacement choke 324 could also be used in the other embodiments, as described for the
All embodiments of the invention could be provided with a guide pipe, such as that shown in
In alternative embodiments, the actuating means of
Although the above disclosures principally refer to the production wing branch and the production choke, the invention could equally be applied to a choke body of the annulus wing branch.
In the
Many different types of processing apparatus could be used. Typically, the processing apparatus comprises at least one of: a pump; a process fluid turbine; injection apparatus; chemical injection apparatus; a fluid riser; measurement apparatus; temperature measurement apparatus; flow rate measurement apparatus; constitution measurement apparatus; consistency measurement apparatus; gas separation apparatus; water separation apparatus; solids separation apparatus; and hydrocarbon separation apparatus.
The processing apparatus could comprise a pump or process fluid turbine, for boosting the pressure of the fluid. Alternatively, or additionally, the processing apparatus could inject gas, steam, sea water, drill cuttings or waste material into the fluids. The injection of gas could be advantageous, as it would give the fluids “lift”, making them easier to pump. The addition of steam has the effect of adding energy to the fluids.
Injecting sea water into a well could be useful to boost the formation pressure for recovery of hydrocarbons from the well, and to maintain the pressure in the underground formation against collapse. Also, injecting waste gases or drill cuttings etc into a well obviates the need to dispose of these at the surface, which can prove expensive and environmentally damaging.
The processing apparatus could also enable chemicals to be added to the fluids, e.g. viscosity moderators, which thin out the fluids, making them easier to pump, or pipe skin friction moderators, which minimise the friction between the fluids and the pipes. Further examples of chemicals which could be injected are surfactants, refrigerants, and well fracturing chemicals. The processing apparatus could also comprise injection water electrolysis equipment.
The processing apparatus could also comprise a fluid riser, which could provide an alternative route between the well bore and the surface. This could be very useful if, for example, the flowline 206 becomes blocked.
Alternatively, processing apparatus could comprise separation equipment e.g. for separating gas, water, sand/debris and/or hydrocarbons. The separated component(s) could be siphoned off via one or more additional process conduits.
The processing apparatus could alternatively or additionally include measurement apparatus, e.g. for measuring the temperature/flow rate/constitution/consistency, etc. The temperature could then be compared to temperature readings taken from the bottom of the well to calculate the temperature change in produced fluids. Furthermore, the processing apparatus could include injection water electrolysis equipment.
This application is a continuation of U.S. application Ser. No. 14/282,937 filed May 20, 2014, which is a continuation of U.S. application Ser. No. 13/267,039 (now U.S. Pat. No. 8,776,891) filed Oct. 6, 2011, which is a divisional of U.S. application Ser. No. 10/590,563 (now U.S. Pat. No. 8,066,076) filed Dec. 13, 2007, which is a U.S. National Phase Application of PCT/GB2005/000725 filed Feb. 25, 2005, which claims the benefit of U.S. Provisional Application No. 60/548,727 filed Feb. 26, 2004, all of which are incorporated herein by reference in their entireties for all purposes.
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| WO 0070185 | Nov 2000 | WO |
| Number | Date | Country | |
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| 20160160613 A1 | Jun 2016 | US |
| Number | Date | Country | |
|---|---|---|---|
| 60548727 | Feb 2004 | US |
| Number | Date | Country | |
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| Parent | 10590563 | US | |
| Child | 13267039 | US |
| Number | Date | Country | |
|---|---|---|---|
| Parent | 14282937 | May 2014 | US |
| Child | 15043995 | US | |
| Parent | 13267039 | Oct 2011 | US |
| Child | 14282937 | US |
