U.S. patent application number 15/238663 was filed with the patent office on 2017-03-09 for riser gas handling system.
The applicant listed for this patent is Cameron International Corporation. Invention is credited to Brian Patrick Garrett, David L. Gilmore, Nicholas Blake Scholz, Terry Jason Smith, Martin Tindle.
Application Number | 20170067295 15/238663 |
Document ID | / |
Family ID | 51522322 |
Filed Date | 2017-03-09 |
United States Patent
Application |
20170067295 |
Kind Code |
A1 |
Gilmore; David L. ; et
al. |
March 9, 2017 |
RISER GAS HANDLING SYSTEM
Abstract
A system including a modular riser gas handling system
configured to couple to and be disposed vertically below a
telescoping joint, wherein the modular riser gas handling system
includes a diverter assembly configured to couple to and divert a
flow of material into and out of a riser, and an annular blow out
preventer (BOP) assembly configured to couple to the diverter
assembly.
Inventors: |
Gilmore; David L.; (Baytown,
TX) ; Smith; Terry Jason; (Houston, TX) ;
Tindle; Martin; (Houston, TX) ; Garrett; Brian
Patrick; (Kingwood, TX) ; Scholz; Nicholas Blake;
(Cypress, TX) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
Cameron International Corporation |
Houston |
TX |
US |
|
|
Family ID: |
51522322 |
Appl. No.: |
15/238663 |
Filed: |
August 16, 2016 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
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13893190 |
May 13, 2013 |
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15238663 |
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61801884 |
Mar 15, 2013 |
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Current U.S.
Class: |
1/1 |
Current CPC
Class: |
E21B 33/035 20130101;
E21B 33/085 20130101; E21B 33/064 20130101; E21B 17/006 20130101;
E21B 33/038 20130101; E21B 19/004 20130101; E21B 17/01 20130101;
E21B 21/08 20130101 |
International
Class: |
E21B 17/00 20060101
E21B017/00; E21B 19/00 20060101 E21B019/00; E21B 33/064 20060101
E21B033/064; E21B 17/01 20060101 E21B017/01; E21B 33/08 20060101
E21B033/08 |
Claims
1. A riser package for use on a rig, comprising: a rotating control
device coupled below a telescopic joint and having a rotating seal
operable to sealingly engage a tubular string disposed through the
riser package; an annular sealing device coupled below the rotating
control device, wherein the annular sealing device is operable to
close off the entire flow bore of the annular sealing device to
prevent fluid from flowing up through a flow bore of the riser
package past the annular sealing device; a flow control device
coupled below the annular sealing device and having one or more
first control lines that provide fluid communication between the
flow control device and a control system located on the rig,
wherein the flow control device is operable to divert fluid flowing
up through the flow bore of the riser package to the control system
located on the rig via the first control lines; a riser string
coupled below the flow control device; and a blow out preventer
coupled below the riser string and having one or more second
control lines that provide fluid communication between the blow out
preventer and equipment located on the rig.
2. The riser package of claim 1, wherein the annular sealing device
comprises a sealing element and a piston for forcing the sealing
element into a closed position to close off the entire flow bore of
the annular sealing device.
3. The riser package of claim 2, further comprising an accumulator
disposed adjacent to the annular sealing device for supplying
hydraulic fluid to actuate the piston.
4. The riser package of claim 2, wherein the flow control device
comprises a central flow bore and a lateral flow bore that
intersects the central flow bore for diverting fluid flow from the
flow bore of the riser package to the control system.
5. The riser package of claim 4, further comprising a hydraulically
actuated valve for opening and closing fluid flow between the
lateral flow bore and a control line that provides fluid
communication to the control system.
6. The riser package of claim 1, wherein the annular sealing device
is operable to sealingly engage the tubular string disposed through
the riser package, wherein the annular sealing device comprises a
non-rotating sealing element to sealingly engage the tubular
string; and wherein the flow control device is operable to divert
fluid flow from an annulus formed between an outer surface of the
tubular string and an inner surface of the riser package to the
control system located on the rig.
7. The riser package of claim 6, wherein the annular sealing device
comprises a hydraulically actuated piston operable to force the
sealing element into engagement with the tubular string.
8. The riser package of claim 6, wherein the flow control device
comprises a central flow bore and a lateral flow bore that
intersects the central flow bore for diverting fluid flow from the
annulus to the control system.
9. The riser package of claim 8, further comprising a hydraulically
actuated valve for opening and closing fluid flow between the
lateral flow bore and a control line that provides fluid
communication to the control system.
10. The riser package of claim 1, further comprising a tensioned
slip ring coupled to the telescopic joint and disposed above the
rotating control device.
11. The riser package of claim 1, wherein the second control lines
are coupled to a flanged connection of at least one of the rotating
control device, the annular sealing device, and the flow control
device.
12. The riser package of claim 1, wherein the control system
located on the rig is configured to reduce the pressure of fluid
from the first control lines, separate the fluid from the first
control lines into one or more components, or direct the fluid from
the first control lines over port or starboard sides of the
rig.
13. A method of handling fluid flow through a riser package that is
supported by a rig, comprising: providing a rotating control device
coupled below a telescopic joint and having a rotating seal
operable to sealingly engage a tubular string disposed through the
riser package; providing an annular sealing device operable to
close off the entire flow bore of the annular sealing device to
prevent fluid from flowing up through a flow bore of the riser
package past the annular sealing device, wherein the annular
sealing device is coupled below the rotating control device;
providing a flow control device operable to divert fluid flowing up
through the flow bore of the riser package to a control system
located on the rig via one or more first control lines that provide
fluid communication between the flow control device and the control
system, wherein the flow control device is coupled below the
annular sealing device; and providing a blow out preventer coupled
below the riser package and having one or more second control lines
that provide fluid communication between the blow out preventer and
equipment located on the rig.
14. The method of claim 13, wherein the annular sealing device
comprises a sealing element and a piston operable to force the
sealing element into a position to completely close off fluid flow
through the flow bore of the annular sealing device.
15. The method of claim 13, wherein the flow control device
comprises a hydraulically actuated valve operable to open and close
fluid flow between the flow control device and the control
system.
16. The method of claim 13, wherein the annular sealing device
comprises a non-rotating sealing element to sealingly engage the
tubular string, and wherein the flow control device is operable to
divert fluid flow from an annulus formed between an outer surface
of the tubular string and an inner surface of the riser package to
the control system located on the rig.
17. The method of claim 16, wherein the flow control device
comprises a hydraulically actuated valve operable to open and close
fluid flow between the flow control device and the control
system.
18. The method of claim 13, further comprising coupling a tensioned
slip ring to the telescopic joint at a position above the rotating
control device.
19. A method of installing a riser package for use on a rig,
comprising: lowering a riser string through a first tubular
handling device located on the rig floor; moving the riser string
out of alignment with the first tubular handling device while
supporting the riser string using a second tubular handling device
located below the first tubular handling device; moving a fluid
control system into alignment with and below the first tubular
handling system; supporting the fluid control system using the
first tubular handling system; moving the riser string back into
alignment with the first tubular handling system; connecting the
fluid control system to the riser string; supporting the fluid
control system and the riser string using the first tubular
handling device; and lowering the fluid control system and the
riser string to an operating position.
20. The method of claim 19, wherein the second tubular handling
device comprises a spider disposed on a trolley located in a moon
pool area below the rig floor.
21. The method of claim 20, further comprising moving the second
tubular handling device into engagement with the riser string using
the trolley to support the riser string using the second tubular
handling device.
22. The method of claim 21, further comprising connecting the fluid
control system to a telescopic joint that is supported by the first
tubular handling device, then moving the riser string back into
alignment with the first tubular handling device, and then
connecting the fluid control system to the riser string.
23. The riser package of claim 1, wherein the riser package
comprises a modular riser gas handling system having the rotating
control device as a first modular unit, the annular sealing device
as a second modular unit, and the flow control device as a third
modular unit removably coupled together.
24. The riser package of claim 23, wherein the annular sealing
device comprises an annular blow out preventer (BOP) and the flow
control device comprises a diverter assembly.
25. The riser package of claim 23, wherein each of the first,
second, and third modular units comprises one or more lines
extending between opposite flanges of the respective modular unit,
wherein adjacent pairs of the first, second, and third modular
units are configured to removably couple together at adjacent pairs
of the flanges and adjacent pairs of the one or more lines.
26. The method of claim 13, comprising handling the fluid flow with
a modular riser gas handling system having the rotating control
device as a first modular unit, the annular sealing device as a
second modular unit, and the flow control device as a third modular
unit.
27. The method of claim 26, wherein each of the first, second, and
third modular units comprises one or more lines extending between
opposite flanges of the respective modular unit, wherein adjacent
pairs of the first, second, and third modular units are configured
to removably couple together at adjacent pairs of the flanges and
adjacent pairs of the one or more lines.
28. The method of claim 19, comprising removably coupling together
a modular riser gas handling system having a rotating control
device as a first modular unit, an annular sealing device as a
second modular unit, and a flow control device as a third modular
unit.
29. The method of claim 28, wherein each of the first, second, and
third modular units comprises one or more lines extending between
opposite flanges of the respective modular unit, wherein adjacent
pairs of the first, second, and third modular units are configured
to removably couple together at adjacent pairs of the flanges and
adjacent pairs of the one or more lines.
30. A system, comprising: a modular riser gas handling system
configured to couple to and be disposed vertically below a
telescoping joint, wherein the modular riser gas handling system
comprises at least two modular units selected from: a first modular
unit comprising a rotating control unit; a second modular unit
comprising an annular blow out preventer (BOP); or a third modular
unit comprising a diverter assembly.
Description
CROSS-REFERENCE TO RELATED APPLICATIONS
[0001] This Application is a Continuation that claims benefit of
U.S. Non-Provisional Patent Application Ser. No. 13/893,190,
entitled "Riser Gas Handling System," filed on May 13, 2013, which
is hereby incorporated by reference in its entirety, which claims
benefit of U.S. Provisional Patent Application No. 61/801,884,
entitled "Riser Gas Handling System", filed Mar. 15, 2013, which is
hereby incorporated by reference in its entirety.
BACKGROUND
[0002] This section is intended to introduce the reader to various
aspects of art that may be related to various aspects of the
present invention, which are described and/or claimed below. This
discussion is believed to be helpful in providing the reader with
background information to facilitate a better understanding of the
various aspects of the present invention. According, it should be
understood that these statements are to be read in this light, and
not as admissions of prior art.
[0003] Natural resources, such as oil and gas, are used as fuel to
power vehicles, heat homes, and generate electricity, in addition
to a myriad of other uses. Once a desired resource is discovered
below the surface of the earth, drilling and production systems are
often employed to access and extract the resource. These systems
may be located offshore depending on the location of a desired
resource. These systems enable drilling and/or extraction
operations.
BRIEF DESCRIPTION OF THE DRAWINGS
[0004] Various features, aspects, and advantages of the present
invention will become better understood when the following detailed
description is read with reference to the accompanying figures in
which like characters represent like parts throughout the figures,
wherein:
[0005] FIG. 1 a schematic of a mineral extraction system with a
riser gas handler system according to an embodiment;
[0006] FIG. 2 a schematic of a mineral extraction system with a
riser gas handler system according to an embodiment;
[0007] FIG. 3 is a front view of a riser gas handler system
according to an embodiment;
[0008] FIG. 4 is a front view of a rotating control unit according
to an embodiment;
[0009] FIG. 5 is a front view of a riser gas handler system
according to an embodiment;
[0010] FIG. 6 is a front view of diverter according to an
embodiment;
[0011] FIG. 7 is a front view of an annular blowout preventer
according to an embodiment;
[0012] FIG. 8 is a front view of a riser gas handler system
according to an embodiment; and
[0013] FIG. 9 is a cross-sectional view of a diverter according to
an embodiment.
DETAILED DESCRIPTION OF SPECIFIC EMBODIMENTS
[0014] One or more specific embodiments of the present invention
will be described below. These described embodiments are only
exemplary of the present invention. Additionally, in an effort to
provide a concise description of these exemplary embodiments, all
features of an actual implementation may not be described in the
specification. It should be appreciated that in the development of
any such actual implementation, as in any engineering or design
project, numerous implementation-specific decisions must be made to
achieve the developers' specific goals, such as compliance with
system-related and business-related constraints, which may vary
from one implementation to another. Moreover, it should be
appreciated that such a development effort might be complex and
time consuming, but would nevertheless be a routine undertaking of
design, fabrication, and manufacture for those of ordinary skill
having the benefit of this disclosure.
[0015] When introducing elements of various embodiments of the
present invention, the articles "a," "an," "the," and "said" are
intended to mean that there are one or more of the elements. The
terms "comprising," "including," and "having" are intended to be
inclusive and mean that there may be additional elements other than
the listed elements. Moreover, the use of "top," "bottom," "above,"
"below," and variations of these terms is made for convenience, but
does not require any particular orientation of the components.
[0016] The disclosed embodiments include a modular riser gas
handling system capable of changing configuration depending on the
type of drilling operation. Specifically, the modular riser gas
handling system may include separable assemblies (e.g., rotating
control unit, annular BOP, diverter) capable of coupling and
decoupling to adjust for different drilling operations. In
operation, the riser gas handling system blocks the flow materials
(e.g., mud, cuttings, natural resources) to the drill floor of a
platform or ship by diverting the materials to another location.
However, different types of drilling operations may involve
different methods with different equipments needs. For example, in
managed pressure drilling operations the riser gas handling system
may include a rotating control unit assembly, an annular BOP
assembly, and a diverter assembly. However, in another drilling
operation a rotating control unit may be unnecessary. Accordingly,
the modularity of the riser gas handling system enables the
selection and exclusion of different pieces of equipment depending
on the drilling operation. Moreover, the modularity of the riser
gas handling system 12 facilitates storage, movement, and assembly
on site.
[0017] FIG. 1 is a schematic of a mineral extraction system 10 with
a riser gas handling system 12. The mineral extraction system 10 is
used to extract oil, natural gas, and other natural resources from
a subsea mineral reservoir 14. As illustrated, a ship or platform
16 positions and supports the mineral extraction system 10 over a
mineral reservoir 14 enabling the mineral extraction system 10 to
drill a well 18 through the sea floor 20. The mineral extraction
system 10 includes a wellhead 22 to that forms a structural and
pressure containing interface between the well 18 and the sea floor
20. Attached to the wellhead 22 is a stack 24. The stack 24 may
include among other items blowout preventers (BOPS) that enable
pressure control during drilling operations. In order to drill the
well 18, an outer drill string 25 couples the ship or platform to
the wellhead 22. The outer drill string 25 may include a
telescoping joint 26 and a riser 28. The telescoping joint 26
enables the mineral extraction system 10 to flexible respond to up
and down movement of the ship or platform 16 on an unstable sea
surface.
[0018] In order to drill the well 18, an inner drill string 29
(i.e., a drill and drill pipe) passes through the telescoping joint
26 and the riser 28 to the sea floor 20. During drilling operations
the inner drill string 29 drills through the sea floor as drilling
mud is pumped through the inner drill string 29 to force the
cuttings out of the well 18 and back up the outer drill string 25
(i.e., in a space 31 between the outer drill string 25 and the
inner drill string 29) to the drill ship or platform 16. When the
well 18 reaches the mineral reservoir 14 natural resources (e.g.,
natural gas and oil) start flowing through the wellhead 22, the
riser 28, and the telescoping joint 26 to the ship or platform 16.
As natural gas reaches the ship 16, a diverter system 30 diverts
the mud, cuttings, and natural resources for separation. Once
separated, natural gas may be sent to a flare 32 to be burned.
However, in certain circumstances it may be desirable to divert the
mud, cuttings, and natural resources away from a ship's drill
floor. Accordingly, the mineral extraction system 10 includes a
riser gas handling system 12 that enables diversion of mud,
cuttings, and natural resources before they reach a ship's drill
floor.
[0019] The riser gas handling system 12 may include an annular BOP
assembly 34 and a diverter assembly 36. In some embodiments, the
riser gas handler 12 may be a modular system wherein the annular
BOP assembly 34 and the diverter assembly 36 are separable
components capable of on-site assembly. The riser gas handling
system 12 uses the annular BOP assembly 34 and the diverter
assembly 36 to stop and divert the flow of natural resources from
the well 18, which would normally pass through the outer drill
string 25 that couples between the ship or platform 16 and the
wellhead 22. Specifically, when the annular BOP assembly 34 closes
it prevents natural resources from continuing through the outer
drill string 25 to the ship or platform 16. The diverter assembly
36 may then divert the flow of natural resources through drape
hoses 38 to the ship or platform 16 or prevent all flow of natural
resources out of the well 18.
[0020] In operation, the riser gas handling system 12 may be used
for different reasons and in different circumstances. For example,
during drilling operations it may be desirable to temporarily block
the flow of all natural resources from the well 18. In another
situation, it may be desirable to divert the flow of natural
resources from entering the ship or platform 16 near or at a drill
floor. In still another situation, it may be desirable to divert
natural resources in order to conduct maintenance on mineral
extraction equipment above the annular BOP assembly 34. Maintenance
may include replacement or repair of the telescoping joint 26,
among other pieces of equipment. The riser gas handling system 12
may also reduce maintenance and increase the durability of the
telescoping joint 26. Specifically, by blocking the flow of natural
resources through the telescoping joint 26 the riser gas handling
system 12 may increase the longevity of seals (i.e., packers)
within the telescoping joint 26.
[0021] FIG. 2 is a schematic of another mineral extraction system
10 with a riser gas handling system 12. The mineral extraction
system 10 of FIG. 2 may use managed pressure drilling to drill
through a sea floor made of softer materials (i.e., materials other
than only hard rock). Managed pressure drilling regulates the
pressure and flow of mud flowing through the inner drill string to
ensure that the mud flow into the well 18 does not over pressurize
the well 18 (i.e., expand the well 18) or allow the well to
collapse under its own weight. The ability to manage the drill mud
pressure therefore enables drilling of mineral reservoirs 14 in
locations with softer sea beds.
[0022] The riser gas handling system 12 of FIG. 2 is a modular
system for managed pressure drilling. As illustrated, the riser gas
handling system 12 includes three components the annular BOP
assembly 34, the diverter assembly 36, and the rotating control
unit assembly 40. In operation, the rotating control unit assembly
40 forms a seal between the inner drill string 29 and the outer
drill string 25 (e.g., the telescoping joint 26), which prevents
mud, cutting, and natural resources from flowing through the
telescoping joint 26 and into the drill floor of a platform or ship
16. The rotating control unit assembly 40 therefore blocks CO2,
H2S, corrosive mud, shallow gas, and unexpected surges of material
flowing through the outer drill string 25 from entering the drill
floor. Instead, the mud, cuttings, and natural resources return to
the ship or platform 16 through the drape hoses 38 coupled to the
diverter assembly 36. As explained above, the modularity of the
riser gas handling system 12 enables maintenance on mineral
extraction equipment above the annular BOP assembly 34. Maintenance
may include replacement or repair of the telescoping joint 26, the
rotating control unit assembly 40, among other pieces of equipment.
Moreover, the modularity of the riser gas handling system 12
facilitates storage, movement, assembly on site, and as will be
explained in further detail below enables different configurations
depending on the needs of a particular drilling operation.
[0023] FIG. 3 is a front view of a riser gas handling system 12 in
one configuration. In the illustrated embodiment, the riser gas
handling system 12 includes an annular BOP assembly 34 and a
diverter assembly 36 combined together. However, in managed
pressure drilling operations, the riser gas handling system 12 may
change configurations by coupling the annular BOP assembly 34 and
the diverter assembly 36 to a rotating control unit assembly 40.
The modularity of the riser gas handling system 12 enables on-site
modification to facilitate different kinds of drilling
operations.
[0024] As illustrated, the riser gas handling system 12 includes an
upper BOP spool connector 60 with a connector flange 62. The upper
BOP spool adapter connector 60 enables the annular BOP assembly 34
with the annular BOP 63 to couple to other components in the
mineral extraction system 10. For example, during managed pressure
drilling operations the upper BOP spool connector 60 enables the
annular BOP assembly 34 to couple to a rotating control unit
assembly 40. In another situation, the upper BOP spool connector 60
may couple to the telescoping joint 26. On the opposite end of the
riser gas handling system 12 is a lower diverter spool connector 64
coupled to the annular BOP 63. The lower diverter spool connector
64 includes a connector flange 66 that enables the lower diverter
spool connector 64 to couple to the riser 28, placing the riser gas
handling system 12 in the fluid path of mud, cutting, and natural
resources flowing through the riser 28 to the platform or ship 16
above. In between the upper spool connector 60 and the lower
diverter spool connector 64 are multiple lines or hoses 68. The
lines 68 may be hydraulic lines, mud boost lines, control lines,
fluid lines, or a combination thereof. The lines 68 on the riser
gas handling system 12 enable fluid communication with lines above
and below the riser gas handler 12.
[0025] In order to divert mud, cuttings, and natural resources from
coming through the riser 28, the diverter assembly 36 includes
apertures 69 in the lower diverter spool connector 64. The flange
spools 70 couple to the apertures 69 and divert materials flowing
through the riser 28 towards valves 72. When open the valves 72
divert material to the gooseneck connection 74 through valve
connectors 76. As illustrated, the gooseneck connectors 74 form a
semi-annular shape with drape connection ports 78. The drape hoses
38 are then able to couple to these ports 78 enabling material to
flow to the platform or ship 16. When connected, the drape hoses 38
may move with subsea currents creating torque on the flange spools
70. In some embodiments, the riser gas handler 12 includes
gooseneck support bracket(s) 80. The bracket(s) 80 may relieve or
block rotational stress on the flange spools 70 increasing the
durability of the diverter assembly 36.
[0026] In operation, the valves 72 open and close in response to
the hydraulics stored in accumulators 82. As explained above, the
riser gas handling system 12 may be used for different reasons and
in different circumstances. For example, during drilling operations
it may be desirable to temporarily block the flow of all natural
resources from the well 18. In another situation, it may be
desirable to divert the flow of natural resources from entering the
ship or platform 16 near or at a drill floor. In still another
situation, it may be desirable to divert natural resources in order
to conduct maintenance on mineral extraction equipment above the
annular BOP assembly 34. Accordingly, the valves 72 may be opened
or closed depending on the need to divert materials or to stop the
flow of all materials to the ship or platform 16. However, in other
embodiments, the diverter system 36 may facilitate the injection of
fluids (e.g., mud, chemicals, water) into the outer drill string 25
through one or more of the gooseneck connections 74. In still other
embodiments, the diverter assembly 36 may facilitate injection of
materials and the extraction of materials through different
gooseneck connections 74 and valves 72 simultaneously or by
alternating between injection and extraction.
[0027] FIG. 4 is a front view of a rotating control unit (RCU)
assembly 40. As explained above, the modularity of the riser gas
handling system 12 enables the attachment and detachment of the RCU
assembly 40, depending on the drilling operation. The RCU assembly
40 includes an RCU 41 coupled to a lower RCU spool connector 100.
The lower RCU spool connector 100 includes a connecting flange 102
that enables coupling of the RCU assembly 40 to the connecting
flange of a BOP spool connector. Opposite the lower RCU spool
connector 100 is an upper RCU spool connector 104 with a connector
flange 106. The upper RCU spool connector 104 couples to the RCU 41
opposite the lower RCU spool connector 100 and enables coupling to
the telescoping joint 26. In between the upper RCU spool connector
104 and the lower RCU spool connector 100 are multiple lines or
hoses 108. The lines 108 may be hydraulic lines, mud boost lines,
control lines, fluid lines, or a combination thereof. The lines 108
on the RCU assembly 40 enable continued fluid communication with
lines above and below the RCU assembly 40. In some embodiments, the
RCU assembly 40 may include support clamp connections 110 to
provide additional support for the lines 108.
[0028] FIG. 5 is a front view of an embodiment of a riser gas
handling system 12 including the annular BOP assembly 34, the
diverter assembly 36, and the RCU assembly 40. As illustrated, the
connector flange 102 of the lower RCU spool connector 100 couples
to the connector flange 62 of the upper BOP spool connector 60.
Furthermore, the connection of the lower RCU spool connector 100 to
the upper BOP spool connector 60, connects the lines 108 to the
lines 68 enabling fluid communication between lines above RCU
assembly 40 and lines below the diverter assembly 36. The
modularity of the riser gas handling system 12 enables the RCU
assembly 40 to couple and decouple, which increases the flexibility
of the riser gas handling system 12 to operate in different
drilling operations.
[0029] FIG. 6 is a front view of diverter assembly 36 capable of
coupling to an annular BOP assembly 34 in a riser gas handling
system 12. The diverter assembly 36 includes a multi-port spool 130
with upper and lower connector flanges 132 and 134. The connector
flanges 132 and 134 couple the multi-port spool 130 to neighboring
components in the mineral extraction system 10. Specifically, the
upper connector flange 134 enables attachment to an annular BOP
assembly 34, while the lower connector flange 132 enables
attachment to the riser 28. In between the connector flanges 132
and 134 of the multi-port spool 130 are multiple lines or hoses
135. The lines 135 may be hydraulic lines, mud boost lines, control
lines, fluid lines, or a combination thereof. The lines 135 on the
diverter assembly 36 enable continued fluid communication with
lines above and below the diverter assembly 36.
[0030] As explained above, the diverter assembly 36 may divert mud,
cuttings, and natural resources from coming through the riser 28
through apertures 136. Coupled to the apertures 136 are diverters
138 that enable material to flow out of the multi-port spool 130 to
the valves 140. When open the valves 140 divert material to the
gooseneck connection 142 through valve connectors 144. As
illustrated, the gooseneck connectors 142 form a semi-annular shape
with drape connection ports 146. The drape hoses 38 are then able
to couple to these ports 146 facilitating material flow to the
platform or ship 16.
[0031] In operation, the valves 140 open and close in response to
the hydraulics stored in accumulators 148. As explained above, the
riser gas handling system 12 may be used for different reasons and
in different circumstances. For example, during drilling operations
it may be desirable to temporarily block the flow of all natural
resources from the well 18. In another situation, it may be
desirable to divert the flow of natural resources from entering the
ship or platform 16 near or at a drill floor. In still another
situation, it may be desirable to divert natural resources in order
to conduct maintenance on mineral extraction equipment above the
annular BOP assembly 34. Accordingly, the valves 140 may be opened
or closed depending on the need to divert materials or to stop the
flow of all materials to the ship or platform 16.
[0032] FIG. 7 is a front view of an annular BOP assembly 34. The
annular BOP assembly 34 includes an annular BOP 168 between a lower
BOP spool connector 170 and an upper BOP spool connector 172. The
lower BOP spool connector 170 includes a connecting flange 174 that
enables coupling of the annular BOP assembly 34 to the diverter
assembly 36. The annular BOP assembly 34 also includes an upper BOP
spool connector 172 with connector flange 176. The connector flange
176 of the upper BOP spool connector 172 enables the annular BOP
assembly 34 to couple to the telescoping joint 26, or the rotating
control unit assembly 40, among other pieces of equipment. In
between the lower BOP spool connector 170 and the upper BOP spool
connector 172 are multiple lines or hoses 178. The lines 178 may be
hydraulic lines, mud boost lines, control lines, fluid lines, or a
combination thereof. The lines 178 on the annular BOP assembly 34
enable continued fluid communication with lines above and below the
annular BOP assembly 34.
[0033] FIG. 8 is a front view of a riser gas handling system 12. In
the illustrated configuration, the modular riser gas handling
system 12 couples all of the assemblies together (e.g., the
diverter assembly 36, the annular BOP assembly 34, and the RCU
assembly 40). Specifically, the connection flange 134 of the
diverter assembly 36 couples to the connector flange 174 of the
annular BOP assembly 34, and the annular BOP connector flange 176
couples to the connector flange 102 of the RCU assembly 40. The
connection of the diverter assembly 36, the annular BOP assembly
34, and the RCU assembly 40 enables fluid communication between
lines above RCU assembly 40 and lines below the diverter assembly
36. In the illustrated configuration, the riser gas handling system
12 may assist in managed pressure drilling operations. However, the
riser gas handling system 12 may have different configurations
including a configuration with only the diverter assembly 36 and
the annular BOP assembly 34. The modularity of the riser gas
handling system 12 enables on-site modification to facilitate
different kinds of drilling operations, as well as replacement of
different components in the riser gas handling system 12.
[0034] FIG. 9 is a cross-sectional view of a diverter assembly 36
coupled to the annular BOP assembly 34. As explained above, the
riser gas handler assembly 12 may block the flow of material 200
(e.g., mud, cuttings, natural resources) through the outer drill
string 25 (i.e., through the telescoping joint 26) with either an
annular BOP assembly and/or an RCU assembly 40. When the riser gas
handling system 12 blocks the flow material 200 the material 200
may remain within the riser 28 or be redirected through the
diverter assembly 36. As illustrated, the valves 140 of the
diverter system 36 are open enabling the flow of material 200
through the diverter system 36 to the gooseneck connections 142
where the material 200 enters the drape hoses 38 for deliver to the
platform or ship 16. However, in other embodiments, the diverter
system 36 may facilitate the injection of fluids (e.g., mud,
chemicals, water) into the outer drill string 25 through the
gooseneck connections 142. In still other embodiments, the diverter
assembly 36 may facilitate injection of fluids and the extraction
of the materials 200 through different gooseneck connection 142 and
valves 140 simultaneously or by alternating between injection and
extraction.
[0035] While the invention may be susceptible to various
modifications and alternative forms, specific embodiments have been
shown by way of example in the drawings and have been described in
detail herein. However, it should be understood that the invention
is not intended to be limited to the particular forms disclosed.
Rather, the invention is to cover all modifications, equivalents,
and alternatives falling within the spirit and scope of the
invention as defined by the following appended claims.
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