U.S. patent application number 16/280506 was filed with the patent office on 2019-07-18 for managed pressure drilling manifold, modules, and methods.
The applicant listed for this patent is TECH ENERGY PRODUCTS, L.L.C.. Invention is credited to Barton Hickie.
Application Number | 20190218872 16/280506 |
Document ID | / |
Family ID | 63672226 |
Filed Date | 2019-07-18 |
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United States Patent
Application |
20190218872 |
Kind Code |
A1 |
Hickie; Barton |
July 18, 2019 |
MANAGED PRESSURE DRILLING MANIFOLD, MODULES, AND METHODS
Abstract
A managed pressure drilling ("MPD") manifold is adapted to
receive drilling mud from a wellbore during oil and gas drilling
operations. The MPD manifold includes one or more drilling
chokes.
Inventors: |
Hickie; Barton; (Oklahoma
City, OK) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
TECH ENERGY PRODUCTS, L.L.C. |
BOSSIER CITY |
LA |
US |
|
|
Family ID: |
63672226 |
Appl. No.: |
16/280506 |
Filed: |
February 20, 2019 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
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PCT/US2018/025421 |
Mar 30, 2018 |
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16280506 |
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15704747 |
Sep 14, 2017 |
10253585 |
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PCT/US2018/025421 |
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15704747 |
Sep 14, 2017 |
10253585 |
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15704747 |
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62480158 |
Mar 31, 2017 |
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62576395 |
Oct 24, 2017 |
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62480158 |
Mar 31, 2017 |
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Current U.S.
Class: |
1/1 |
Current CPC
Class: |
E21B 34/16 20130101;
E21B 33/0355 20130101; E21B 41/0092 20130101; E21B 21/106
20130101 |
International
Class: |
E21B 21/10 20060101
E21B021/10; E21B 41/00 20060101 E21B041/00; E21B 34/16 20060101
E21B034/16 |
Claims
1. A method of controlling backpressure of a drilling mud within a
wellbore, the method comprising: receiving the drilling mud from
the wellbore; either: controlling, using one or more drilling
chokes, the backpressure of the drilling mud within the wellbore,
the one or more drilling chokes being part of a first module; or
bypassing the one or more drilling chokes of the first module;
either: measuring, using a flow meter, a flow rate of the drilling
mud received from the wellbore, the flow meter being part of a
second module; or bypassing the flow meter of the second module;
communicating the drilling mud between the first and second modules
using a third module, the third module being configured to support
the second module in either: a generally horizontal orientation; or
a generally vertical orientation; and discharging the drilling
mud.
2. The method of claim 1, wherein the first and second modules are
together mounted to either a skid or a trailer so that, when so
mounted, the first and second modules are together towable between
operational sites.
3. The method of claim 1, wherein the third module comprises first
and second flow blocks operably coupled in parallel between the
first and second modules, the first and second flow blocks each
defining an internal region and first, second, third, fourth, and
fifth fluid passageways extending into the internal region.
4. The method of claim 3, wherein, when the third module supports
the second module in the generally horizontal orientation: the
first module is operably coupled to, and in fluid communication
with, the internal region of the first flow block via the first
fluid passageway thereof, and the second module is operably coupled
to, and in fluid communication with, the internal region of the
first flow block via the second fluid passageway thereof; and the
first module is operably coupled to, and in fluid communication
with, the internal region of the second flow block via the first
fluid passageway thereof, and the second module is operably coupled
to, and in fluid communication with, the internal region of the
second flow block via the second fluid passageway thereof
5. The method of claim 4, wherein, when the third module supports
the second module in the generally vertical orientation: the first
module is operably coupled to, and in fluid communication with, the
internal region of the first flow block via the first fluid
passageway thereof, and the second module is operably coupled to,
and in fluid communication with, the internal region of the first
flow block via the fifth fluid passageway thereof; and the first
module is operably coupled to, and in fluid communication with, the
internal region of the second flow block via the first fluid
passageway thereof, and the second module is operably coupled to,
and in fluid communication with, the internal region of the second
flow block via the fifth fluid passageway thereof.
6. The method of claim 3, wherein the first and second flow blocks
each comprise first, second, third, fourth, fifth, and sixth sides,
the third, fourth, fifth, and sixth sides extending between the
first and second sides, and the first, second, third, fourth, and
fifth fluid passageways extending through the first, second, third,
fourth, and fifth sides.
7. The method of claim 3, wherein the third module further
comprises first, second, third, fourth, and fifth valves, the first
and second valves being operably coupled to, and in fluid
communication with, the first flow block and the respective first
and second modules, the third and fourth valves being operably
coupled to, and in fluid communication with, the second flow block
and the respective first and second modules, and the fifth valve
being operably coupled between, and in fluid communication with,
the first and second flow blocks.
8. The method of claim 7, wherein communicating the drilling mud
between the first and second modules using the third module
comprises: permitting fluid flow from the first flow block to the
second flow block via the second valve, the flow meter, and the
fourth valve; and preventing, or at least reducing, fluid flow from
the first flow block to the second flow block via the fifth valve;
and wherein bypassing the flow meter of the second module
comprises: preventing, or at least reducing, fluid flow from the
first flow block to the second flow block via the second valve, the
flow meter, and the fourth valve; and permitting fluid flow from
the first flow block to the second flow block via the fifth
valve.
9. The method of claim 7, wherein communicating the drilling mud
between the first and second modules using the third module
comprises actuating the first, second, third, fourth, and fifth
valves so that either: the second, third, and fourth valves are
open and the first and fifth valves are closed; or the first,
second, and fourth valves are open and the third and fifth valves
are closed; and wherein bypassing the flow meter of the second
module comprises actuating the first, second, third, fourth, and
fifth valves so that either: the third and fifth valves are open
and the first, second, and fourth valves are closed; or the first
and fifth valves are open and the second, third, and fourth valves
are closed.
10. The method of claim 1, wherein the second module further
comprises first and second flow blocks, and first and second
spools, the first spool being operably coupled to, and in fluid
communication with, the first flow block, the second spool being
operably coupled between, and in fluid communication with, the
first and second flow blocks, and the flow meter being operably
coupled to, and in fluid communication with, the fourth flow
block.
11. The method of claim 1, wherein the flow meter is a coriolis
flow meter.
12. A method of controlling backpressure of a drilling mud within a
wellbore, the method comprising: receiving the drilling mud from
the wellbore; either: controlling, using first and/or second
drilling chokes, the backpressure of the drilling mud within the
wellbore, the first and second drilling chokes being part of a
first module, the first module further comprising first and second
fluid blocks between which the first and second drilling chokes are
operably coupled in parallel; or bypassing the first and second
drilling chokes of the first module; and discharging the drilling
mud.
13. The method of claim 12, wherein the first module further
comprises first, second, third, and fourth valves, the first and
second valves being operably coupled to, and in fluid communication
with, the first fluid block, the third and fourth valves being
operably coupled to, and in fluid communication with, the second
fluid block, the first drilling choke being operably coupled
between, and in fluid communication with, the first and third
valves, and the second drilling choke being operably coupled
between, and in fluid communication with, the second and fourth
valves.
14. The method of claim 13, wherein the first module further
comprises a fifth valve operably coupled between, and in fluid
communication with, the first and second fluid blocks.
15. The method of claim 14, wherein controlling, using the first
and/or second drilling chokes, the backpressure of the drilling mud
within the wellbore comprises: permitting fluid flow from the first
fluid block to the second fluid block via one or both of the
following element combinations: the first valve, the first drilling
choke, and the third valve; and the second valve, the second
drilling choke, and the fourth valve; and preventing, or at least
reducing, fluid flow from the first fluid block to the second fluid
block via the fifth valve; and wherein bypassing the first and
second drilling chokes of the first module comprises: permitting
fluid flow from the first fluid block to the second fluid block via
the fifth valve; and preventing, or at least reducing, fluid flow
from the first fluid block to the second fluid block via each of
the following element combinations: the first valve, the first
drilling choke, and the third valve; and the second valve, the
second drilling choke, and the fourth valve.
16. The method of claim 14, wherein controlling, using the first
and/or second drilling chokes, the backpressure of the drilling mud
within the wellbore comprises actuating the first, second, third,
fourth, and fifth valves so that: the first and third valves are
open and the second, fourth, and fifth valves are closed; the
second and fourth valves are open and the first, third, and fifth
valves are closed; or the first, second, third, and fourth valves
are open and the fifth valve is closed; and wherein bypassing the
first and second drilling chokes of the first module comprises
actuating the first, second, third, fourth, and fifth valves so
that the first, second, third, and fourth valves are closed and the
fifth valve is open.
17. The method of claim 14, wherein the first and second fluid
blocks each define an internal region and first, second, third, and
fourth fluid passageways extending into the internal region.
18. The method of claim 17, wherein the first, second, and fifth
valves are in fluid communication with the internal region of the
first fluid block via the respective first, second, and third fluid
passageways thereof; and wherein the third, fourth, and fifth
valves are in fluid communication with the internal region of the
second fluid block via the respective first, second, and fourth
fluid passageways thereof.
19. The method of claim 18, wherein the first and second fluid
blocks each comprise first and second ends, and first, second,
third, and fourth sides extending between the first and second
ends, the first and second fluid passageways extending through the
first side, and the third and fourth fluid passageways extending
through the second and third sides, respectively.
20. A choke module adapted to receive drilling mud from a wellbore,
the choke module comprising: first and second fluid blocks; and
first and second drilling chokes operably coupled in parallel
between the first and second fluid blocks; wherein each of the
first and second drilling chokes is adapted to control a
backpressure of the drilling mud within the wellbore.
21. The choke module of claim 20, further comprising first, second,
third, and fourth valves, the first and second valves being
operably coupled to, and in fluid communication with, the first
fluid block, the third and fourth valves being operably coupled to,
and in fluid communication with, the second fluid block, the first
drilling choke being operably coupled between, and in fluid
communication with, the first and third valves, and the second
drilling choke being operably coupled between, and in fluid
communication with, the second and fourth valves.
22. The choke module of claim 21, further comprising a fifth valve
operably coupled between, and in fluid communication with, the
first and second fluid blocks.
23. The choke module of claim 22, wherein the choke module is
actuable between: a first configuration in which: fluid flow is
permitted from the first fluid block to the second fluid block via
one or both of the following element combinations: the first valve,
the first drilling choke, and the third valve; and the second
valve, the second drilling choke, and the fourth valve; and fluid
flow is prevented, or at least reduced, from the first fluid block
to the second fluid block via the fifth valve; and a second
configuration in which: fluid flow is permitted from the first
fluid block to the second fluid block via the fifth valve; and
fluid flow is prevented, or at least reduced, from the first fluid
block to the second fluid block via each of the following element
combinations: the first valve, the first drilling choke, and the
third valve; and the second valve, the second drilling choke, and
the fourth valve.
24. The choke module of claim 23, wherein, when the choke module is
in the first configuration, the first, second, third, fourth, and
fifth valves are actuated so that either: the first and third
valves are open and the second, fourth, and fifth valves are
closed; the second and fourth valves are open and the first, third,
and fifth valves are closed; or the first, second, third, and
fourth valves are open and the fifth valve is closed; and wherein,
when the choke module is in the second configuration, the first,
second, third, fourth, and fifth valves are actuated so that the
first, second, third, and fourth valves are closed and the fifth
valve is open.
25. The choke module of claim 22, wherein the first and second
fluid blocks each define an internal region and first, second,
third, and fourth fluid passageways extending into the internal
region.
26. The choke module of claim 25, wherein the first, second, and
fifth valves are in fluid communication with the internal region of
the first fluid block via the respective first, second, and third
fluid passageways thereof; and wherein the third, fourth, and fifth
valves are in fluid communication with the internal region of the
second fluid block via the respective first, second, and fourth
fluid passageways thereof.
27. The choke module of claim 26, wherein the first and second
fluid blocks each comprise first and second ends, and first,
second, third, and fourth sides extending between the first and
second ends, the first and second fluid passageways extending
through the first side, and the third and fourth fluid passageways
extending through the second and third sides, respectively.
Description
CROSS-REFERENCE TO RELATED APPLICATIONS
[0001] This application is a continuation of co-pending
International Patent Application No. PCT/US2018/025421, filed Mar.
30, 2018, the entire disclosure of which is hereby incorporated
herein by reference. International Patent Application No.
PCT/US2018/025421 claims the benefit of the filing date of, and
priority to, U.S. Patent Application No. 62/480,158, filed Mar. 31,
2017, the entire disclosure of which is hereby incorporated herein
by reference. International Patent Application No.
PCT/US2018/025421 also claims the benefit of the filing date of,
and priority to, U.S. patent application Ser. No. 15/704,747, filed
Sep. 14, 2017, the entire disclosure of which is hereby
incorporated herein by reference. International Patent Application
No. PCT/US2018/025421 also claims the benefit of the filing date
of, and priority to, U.S. Patent Application No. 62/576,395, filed
Oct. 24, 2017, the entire disclosure of which is hereby
incorporated herein by reference.
[0002] This application is a continuation-in-part (CIP) of
co-pending U.S. patent application Ser. No. 15/704,747, filed Sep.
14, 2017, the entire disclosure of which is hereby incorporated
herein by reference. U.S. patent application Ser. No. 15/704,747
claims the benefit of the filing date of, and priority to, U.S.
Patent Application No. 62/480,158, filed Mar. 31, 2017, the entire
disclosure of which is hereby incorporated herein by reference.
TECHNICAL FIELD
[0003] The present disclosure relates generally to oil and gas
exploration and production operations and, more particularly, to a
managed pressure drilling ("MPD") manifold used during oil and gas
drilling operations.
BACKGROUND
[0004] An MPD system may include drilling choke(s) and a flow
meter, with the drilling choke(s) and the flow meter being separate
and distinct from one another. The drilling choke(s) are in fluid
communication with a wellbore that traverses a subterranean
formation. As a result, the drilling system may be used to control
backpressure in the wellbore as part of an adaptive drilling
process that allows greater control of the annular pressure profile
throughout the wellbore. During such a process, the flow meter
measures the flow rate of drilling mud received from the wellbore.
In some cases, the configuration of the drilling choke(s) and/or
the flow meter may decrease the efficiency of drilling operations,
thereby presenting a problem for operators dealing with challenges
such as, for example, continuous duty operations, harsh downhole
environments, and multiple extended-reach lateral wells, among
others. Further, the configuration of the drilling choke(s) and/or
the flow meter may adversely affect the transportability and
overall footprint of the drilling choke(s) and/or the flow meter at
the wellsite. Finally, the separate and distinct nature of the
drilling choke(s) and the flow meter can make it difficult to
inspect, service, or repair the drilling choke(s) and/or the flow
meter, and/or to coordinate the inspection, service, repair, or
replacement of the drilling choke(s) and/or the flow meter.
Therefore, what is needed is a method, apparatus, or system that
addresses one or more of the foregoing issues, and/or one or more
other issues.
BRIEF DESCRIPTION OF THE DRAWINGS
[0005] FIG. 1 is a diagrammatic view of a drilling system
including, among other components, an MPD manifold, according to
one or more embodiments of the present disclosure.
[0006] FIG. 2 is a diagrammatic view of the MPD manifold of FIG. 1
in a first configuration, the MPD manifold including a choke
module, a flow meter module, and a valve module, according to one
or more embodiments of the present disclosure.
[0007] FIG. 3 is a diagrammatic view of another embodiment of the
MPD manifold of FIG. 1 in a second configuration, the MPD manifold
including a choke module, a flow meter module, and a valve module,
according to one or more embodiments of the present disclosure.
[0008] FIG. 4(a) is a perspective view of a first embodiment of the
MPD manifold of any one of FIGS. 1-3 with the flow meter module
extending in a generally horizontal orientation, the choke module
of the MPD manifold including a first pair of flow blocks, and the
valve module of the MPD manifold including a second pair of flow
blocks, according to one or more embodiments of the present
disclosure.
[0009] FIG. 4(b) is a left side elevational view of the MPD
manifold of FIG. 4(a), according to one or more embodiments of the
present disclosure.
[0010] FIG. 4(c) is a rear elevational view of the MPD manifold of
FIG. 4(a), according to one or more embodiments of the present
disclosure.
[0011] FIG. 4(d) is a right side elevational view of the MPD
manifold of FIG. 4(a), according to one or more embodiments of the
present disclosure.
[0012] FIG. 4(e) is a front elevational view of the MPD manifold of
FIG. 4(a), according to one or more embodiments of the present
disclosure.
[0013] FIG. 4(f) is a top plan view of the MPD manifold of FIG.
4(a), according to one or more embodiments of the present
disclosure.
[0014] FIG. 5(a) is a perspective view of one of the flow blocks
from the first pair of FIGS. 4(a)-(f), according to one or more
embodiments of the present disclosure.
[0015] FIG. 5(b) is a cross-sectional view of the flow block of
FIG. 5(a), taken along the line 5(b)-5(b) of FIG. 5(a), according
to one or more embodiments of the present disclosure.
[0016] FIG. 6(a) is a perspective view of one of the flow blocks
from the second pair of FIGS. 4(a)-(f), according to one or more
embodiments of the present disclosure.
[0017] FIG. 6(b) is a cross-sectional view of the flow block of
FIG. 6(a), taken along the line 6(b)-6(b) of FIG. 6(a), according
to one or more embodiments of the present disclosure.
[0018] FIG. 7(a) is a perspective view of a second embodiment of
the MPD manifold of any one of FIGS. 1-3 with the flow meter module
extending in a generally vertical orientation, the choke module of
the MPD manifold including the first pair of flow blocks, and the
valve module of the MPD manifold including the second pair of flow
blocks, according to one or more embodiments of the present
disclosure.
[0019] FIG. 7(b) is a left side elevational view of the MPD
manifold of FIG. 7(a), according to one or more embodiments of the
present disclosure.
[0020] FIG. 7(c) is a right side elevational view of the MPD
manifold of FIG. 7(a), according to one or more embodiments of the
present disclosure.
[0021] FIG. 7(d) is a top plan view of the MPD manifold of FIG.
7(a), according to one or more embodiments of the present
disclosure.
[0022] FIG. 8 is a flow chart illustration of a method for
controlling the backpressure of a drilling mud within a wellbore,
according to one or more embodiments of the present disclosure.
[0023] FIG. 9 is a flow chart illustration of another method for
controlling the backpressure of a drilling mud within a wellbore,
according to one or more embodiments of the present disclosure.
[0024] FIG. 10(a) is a perspective view of a third embodiment of
the MPD manifold of any one of FIGS. 1-3 with the flow meter module
extending in a generally horizontal orientation, the choke module
of the MPD manifold including a first pair of flow blocks, and the
valve module of the MPD manifold including the second pair of flow
blocks, according to one or more embodiments of the present
disclosure.
[0025] FIG. 10(b) is a left side elevational view of the MPD
manifold of FIG. 10(a), according to one or more embodiments of the
present disclosure.
[0026] FIG. 10(c) is a rear elevational view of the MPD manifold of
FIG. 10(a), according to one or more embodiments of the present
disclosure.
[0027] FIG. 10(d) is a right side elevational view of the MPD
manifold of FIG. 10(a), according to one or more embodiments of the
present disclosure.
[0028] FIG. 10(e) is a front elevational view of the MPD manifold
of FIG. 10(a), according to one or more embodiments of the present
disclosure.
[0029] FIG. 10(f) is a top plan view of the MPD manifold of FIG.
10(a), according to one or more embodiments of the present
disclosure.
[0030] FIG. 11(a) is a perspective view of one of the flow blocks
from the first pair of FIGS. 10(a)-(f), according to one or more
embodiments of the present disclosure.
[0031] FIG. 11(b) is a cross-sectional view of the flow block of
FIG. 11(a), taken along the line 11(b)-11(b) of FIG. 11(a),
according to one or more embodiments of the present disclosure.
[0032] FIG. 12(a) is a perspective view of a fourth embodiment of
the MPD manifold of any one of FIGS. 1-3 with the flow meter module
extending in a generally vertical orientation, the choke module of
the MPD manifold including the first pair of flow blocks, and the
valve module of the MPD manifold including the second pair of flow
blocks, according to one or more embodiments of the present
disclosure.
[0033] FIG. 12(b) is a left side elevational view of the MPD
manifold of FIG. 12(a), according to one or more embodiments of the
present disclosure.
[0034] FIG. 12(c) is a right side elevational view of the MPD
manifold of FIG. 12(a), according to one or more embodiments of the
present disclosure.
[0035] FIG. 12(d) is a top plan view of the MPD manifold of FIG.
12(a), according to one or more embodiments of the present
disclosure.
[0036] FIG. 13 is a flow chart illustration of a method for
controlling the backpressure of a drilling mud within a wellbore,
according to one or more embodiments of the present disclosure.
[0037] FIG. 14 is a flow chart illustration of another method for
controlling the backpressure of a drilling mud within a wellbore,
according to one or more embodiments of the present disclosure.
[0038] FIG. 15 is a diagrammatic illustration of a control unit
adapted to be connected to one or more components (or
sub-components) of the drilling system of FIG. 1, according to one
or more embodiments of the present disclosure.
[0039] FIG. 16 is a diagrammatic illustration of a computing device
for implementing one or more embodiments of the present
disclosure.
DETAILED DESCRIPTION
[0040] In an embodiment, as illustrated in FIG. 1, a drilling
system is generally referred to by the reference numeral 10 and
includes a wellhead 12, a blowout preventer ("BOP") 14, a rotating
control device ("RCD") 16, a drilling tool 18, an MPD manifold 20,
a mud gas separator ("MGS") 22, a vent or flare 24, a shaker 26,
and a mud pump 28. The wellhead 12 is located at the top or head of
an oil and gas wellbore 29 that penetrates one or more subterranean
formations, and is used in oil and gas exploration and production
operations such as, for example, drilling operations. The BOP 14 is
operably coupled to the wellhead 12 to prevent blowout, i.e., the
uncontrolled release of crude oil and/or natural gas from the
wellbore 29 during drilling operations. The drilling tool 18 is
operably coupled to a drill string (not shown), and extends within
the wellbore 29. The drill string extends into the wellbore 29
through the BOP 14 and the wellhead 12. Moreover, the RCD 16 is
operably coupled to the BOP 14, opposite the wellhead 12, and forms
a friction seal around the drill string. The MPD manifold 20 is
operably coupled to, and in fluid communication with, the RCD 16.
The MGS 22 is operably coupled to, and in fluid communication with,
the MPD manifold 20. The flare 24 and the shaker 26 are both
operably coupled to, and in fluid communication with, the MGS 22.
The mud pump 28 is operably coupled between, and in fluid
communication with, the shaker 26 and the drill string.
[0041] In operation, the drilling system 10 is used to extend the
reach or penetration of the wellbore 29 into the one or more
subterranean formations. To this end, the drill string is rotated
and weight-on-bit is applied to the drilling tool 18, thereby
causing the drilling tool 18 to rotate against the bottom of the
wellbore 29. At the same time, the mud pump 28 circulates drilling
fluid to the drilling tool 18, via the drill string, as indicated
by the arrows 30 and 32. The drilling fluid is discharged from the
drilling tool 18 into the wellbore 29 to clear away drill cuttings
from the drilling tool 18. The drill cuttings are carried back to
the surface by the drilling fluid via an annulus of the wellbore 29
surrounding the drill string, as indicated by the arrow 34. The
drilling fluid and the drill cuttings, in combination, are also
referred to herein as "drilling mud."
[0042] As indicated by the arrow 34 in FIG. 1, the drilling mud
flows into the RCD 16 through the wellhead 12 and the BOP 14. The
RCD 16 diverts the flow of the drilling mud to the MPD manifold 20
while preventing, or at least reducing, communication between the
annulus of the wellbore 29 and atmosphere. In this manner, the RCD
16 enables the drilling system 10 to operate as a closed-loop
system. The MPD manifold 20 receives the drilling mud from the RCD
16, and is adjusted to maintain the desired backpressure within the
wellbore 29, as will be discussed in further detail below. The MGS
22 receives the drilling mud from the MPD manifold 20, and captures
and separates gas from the drilling mud. The captured and separated
gas is sent to the flare 24 to be burnt off Alternatively, the
flare 24 is omitted and the captured and separated gas is
reinjected into the one or more subterranean formations. The shaker
26 receives the drilling mud from the MGS 22, and removes the drill
cuttings therefrom. The mud pump 28 then recirculates the drilling
fluid to the drilling tool 18, via the drill string.
[0043] In an embodiment, as illustrated in FIG. 2 with continuing
reference to FIGS. 1, the MPD manifold 20 includes a choke module
36, a flow meter module 38, and a valve module 40. The choke module
36 is operably coupled to, and adapted to be in fluid communication
with, the flow meter module 38 via the valve module 40. The choke
module 36, the flow meter module 38, and the valve module 40 are
together mounted to a skid 42. In some embodiments, one or more
instruments such as, for example, a temperature sensor 44, a
densometer 46, and one or more pressure sensors, are operably
coupled to the choke module 36. Additionally, one or more
instruments such as, for example, a temperature sensor 48, a
densometer 50, and one or more other pressure sensors, are operably
coupled to the valve module 40. In some embodiments, one or more of
the temperature sensors 44 and 48, one or more of the densometers
46 and 50, and pressure sensor(s) are also mounted to the skid 42.
In some embodiments, one or more of the temperature sensors 44 and
48, one or more of the densometers 46 and 50, and pressure
sensor(s) are part of the MPD manifold 20. In addition to, or
instead of, being mounted to the skid 42, the choke module 36, the
flow meter module 38, and the valve module 40 may be freestanding
on the ground or mounted to a trailer (not shown) that can be towed
between operational sites.
[0044] During the operation of the drilling system 10, the valve
module 40 receives the drilling mud from the RCD 16, as indicated
by arrows 52 and 54. The temperature sensor 48 measures the
temperature of the drilling mud immediately before the drilling mud
is received by the valve module 40. In addition, the densometer 50
measures the density of the drilling mud immediately before the
drilling mud is received by the valve module 40. In some
embodiments, one or more pressure sensors (not shown in FIG. 2)
measure the pressure of the drilling mud immediately before the
drilling mud is received by the valve module 40; in some
embodiments, the temperature sensor 48 and/or the densometer 50
includes the one or more pressure sensors. The valve module 40
routes the drilling mud to the flow meter module 38, as indicated
by arrow 56. The flow meter module 38 measures the flow rate of the
drilling mud before communicating the drilling mud back to the
valve module 40, as indicated by arrow 57. The valve module 40 then
routes the drilling mud to the choke module 36, as indicated by
arrow 58. The choke module 36 is adjusted to maintain the desired
backpressure of the drilling mud within the wellbore 29. The MGS 22
receives the drilling mud from the choke module 36, as indicated by
arrows 60 and 62. The temperature sensor 44 measures the
temperature of the drilling mud immediately after the drilling mud
is discharged from the choke module 36. In addition, the densometer
46 measures the density of the drilling mud immediately after the
drilling mud is discharged from the choke module 36. In some
embodiments, one or more other pressure sensors (not shown in FIG.
2) measure the pressure of the drilling mud immediately after the
drilling mud is discharged from the choke module 36; in some
embodiments, the temperature sensor 44 and/or the densometer 46
includes the one or more other pressure sensors.
[0045] In some embodiments, one of which is described in further
detail below with reference to FIG. 3, the temperature sensor 44
and the densometer 46 are operably coupled to the valve module 40
rather than being operably coupled to the choke module 36.
Additionally, the temperature sensor 48 and the densometer 50 are
operably coupled to the choke module 36 rather than being operably
coupled to the valve module 40. As a result, the choke module 36
receives the drilling mud from the RCD 16 and the MGS 22 receives
the drilling mud from the valve module 40, as will be described in
further detail below with reference to FIG. 3. In some embodiments,
pressure sensor(s) are also operably coupled to the valve module
40. In some embodiments, pressure sensor(s) are also operably
coupled to the choke module 36.
[0046] In an embodiment of the choke module 36, as illustrated in
FIGS. 4(a)-(f) with continuing reference to FIGS. 2 and 3, the
choke module 36 includes flow blocks 64a-b, block valves 66a-e,
flow blocks 68a-b, and drilling chokes 70a-b. The block valves
66a-e are each actuable between an open configuration in which
fluid flow is permitted therethrough, and a closed configuration in
which fluid flow therethrough is prevented, or at least reduced. In
some embodiments, the block valves 66a-e are gate valves.
Alternatively, one or more of the block valves 66a-e may be another
type of valve such as, for example, a plug valve.
[0047] The block valve 66a is operably coupled to the flow block
64a. The flow block 68a is operably coupled to the block valve 66a
via, for example, a spool 72a. The block valve 66a may provide
isolation of the flow block 68a from the flow block 64a. The block
valve 66b is operably coupled to the flow block 64b. The drilling
choke 70a is operably coupled to the block valve 66b, via, for
example, a spool 74a. The block valve 66b may provide isolation of
the drilling choke 70a from the flow block 64b. The drilling choke
70a is operably coupled to the flow block 68a via, for example, a
spool 76a. The block valve 66c is operably coupled to the flow
block 64a adjacent the block valve 66a. The flow block 68b is
operably coupled to the block valve 66c via, for example, a spool
72b. The block valve 66c may provide isolation of the flow block
68b from the flow block 64a. The block valve 66d is operably
coupled to the flow block 64b adjacent the block valve 66b. The
drilling choke 70b is operably coupled to the block valve 66d via,
for example, a spool 74b. The block valve 66d may provide isolation
of the drilling choke 70b from the flow block 64b. The drilling
choke 70b is operably coupled to the flow block 68b via, for
example, a spool 76b. The block valve 66e is operably coupled
between the flow blocks 64a and 64b.
[0048] In some embodiments, each of the drilling chokes 70a and 70b
is a 4-inch inner diameter (ID) choke. In some embodiments, each of
the drilling chokes 70a and 70b defines an inner diameter of about
4 inches.
[0049] The choke module 36 is actuable between a backpressure
control configuration and a choke bypass configuration. In the
backpressure control configuration, the flow block 64b is in fluid
communication with the flow block 64a via one or more of the
drilling chokes 70a and/or 70b. In some embodiments, when the choke
module 36 is in the backpressure control configuration, the flow
block 64b is not in fluid communication with the flow block 64a via
the block valve 66e (i.e., the block valve 66e is closed). During
the operation of the drilling system 10, when the choke module 36
is in the backpressure control configuration, one or more of the
drilling chokes 70a and/or 70b are adjusted to account for changes
in the flow rate of the drilling mud so that the desired
backpressure within the wellbore 29 is maintained. In the choke
bypass configuration, the flow block 64b is in fluid communication
with the flow block 64a via the block valve 66e. In some
embodiments, when the choke module 36 is in the choke bypass
configuration, the flow block 64b is not in fluid communication
with the flow block 64a via the drilling chokes 70a or 70b. In some
embodiments, to enable such fluid communication between the flow
blocks 64a and 64b via the block valve 66e, the block valves 66a-d
are actuated to the closed configuration and the block valve 66e is
actuated to the open configuration.
[0050] In some embodiments, one or more of the drilling chokes 70a
and/or 70b are manual chokes, thus enabling rig personnel to
manually control backpressure within the drilling system 10 when
the choke module 36 is in the backpressure control configuration.
In some embodiments, one or more of the drilling chokes 70a and/or
70b are automatic chokes controlled automatically by electronic
pressure monitoring equipment when the choke module 36 is in the
backpressure control configuration. In some embodiments, one or
more of the drilling chokes 70a and/or 70b are combination
manual/automatic chokes.
[0051] In some embodiments, when the choke module 36 is in the
backpressure control configuration, the flow block 64b is in fluid
communication with the flow block 64a via at least the drilling
choke 70a. To enable such fluid communication between the flow
blocks 64a and 64b via the drilling choke 70a, the block valves 66a
and 66b are actuated to the open configuration, and the block valve
66e is actuated to the closed configuration. As a result, the flow
block 64b is in fluid communication with the flow block 64a via at
least the block valve 66b, the spool 74a, the drilling choke 70a,
the spool 76a, the flow block 68a, the spool 72a, and the block
valve 66a, respectively.
[0052] In some embodiments, when the choke module 36 is in the
backpressure control configuration, the flow block 64b is in fluid
communication with the flow block 64a via at least the drilling
choke 70b. To enable such fluid communication between the flow
blocks 64a and 64b via the drilling choke 70b, the block valves 66c
and 66d are actuated to the open configuration, and the block valve
66e is actuated to the closed configuration. As a result, the flow
block 64b is in fluid communication with the flow block 64a via at
least the block valve 66d, the spool 74b, the drilling choke 70b,
the spool 76b, the flow block 68b, the spool 72b, and the block
valve 66c, respectively.
[0053] In some embodiments, the flow blocks 64a and 64b are
substantially identical to one another and, therefore, in
connection with FIGS. 5(a)-(b), only the flow block 64a will be
described in detail below; however, the description below applies
to both of the flow blocks 64a and 64b. In an embodiment, as
illustrated in FIGS. 5(a)-(b) with continuing reference to FIGS.
4(a)-(f), the flow block 64a includes ends 78a-b and sides 80a-d.
In some embodiments, the ends 78a and 78b are spaced in a
substantially parallel relation. In some embodiments, the sides 80a
and 80b are spaced in a substantially parallel relation, each
extending from the end 78a to the end 78b. In some embodiments, the
sides 80c and 80d are spaced in a substantially parallel relation,
each extending from the end 78a to the end 78b. In some
embodiments, one of which is shown in FIGS. 5(a)-(b), the sides 80a
and 80b are spaced in a substantially parallel relation, and the
sides 80c and 80d are spaced in a substantially parallel relation.
In some embodiments, the sides 80a and 80b are spaced in a
substantially perpendicular relation with the sides 80c and 80d. In
some embodiments, the ends 78a and 78b are spaced in a
substantially perpendicular relation with the sides 80a and 80b. In
some embodiments, the ends 78a and 78b are spaced in a
substantially perpendicular relation with the sides 80c and 80d. In
some embodiments, one of which is shown in FIGS. 5(a)-(b), the ends
78a and 78b are spaced in a substantially perpendicular relation
with the sides 80a, 80b, 80c, and 80d.
[0054] In addition, the flow block 64a defines an internal region
82 and fluid passageways 84a-f. In some embodiments, the fluid
passageway 84a extends through the end 78a of the flow block 64a
into the internal region 82. In some embodiments, the fluid
passageway 84b extends through the end 78b of the flow block 64a
into the internal region 82. In some embodiments, one of which
shown in FIGS. 5(a)-(b), the fluid passageway 84a extends through
the end 78a of the flow block 64a into the internal region 82, and
the fluid passageway 84b extends through the end 78b of the flow
block 64a into the internal region 82. In some embodiments, the
fluid passageways 84a and 84b form a continuous fluid passageway
together with the internal region 82. In some embodiments, the
fluid passageway 84c extends through the side 80a of the flow block
64a into the internal region 82. In some embodiments, the fluid
passageway 84d extends through the side 80b of the flow block 64a
into the internal region 82. In some embodiments, one of which is
shown in FIGS. 5(a)-(b), the fluid passageway 84c extends through
the side 80a of the flow block 64a into the internal region 82, and
the fluid passageway 84d extends through the side 80b of the flow
block 64a into the internal region 82. In some embodiments, the
fluid passageways 84c and 84d form a continuous fluid passageway
together with the internal region 82. In some embodiments, one of
which is shown in FIGS. 5(a)-(b), the fluid passageways 84e and 84f
each extend through the side 80c of the flow block 64a into the
internal region 82. In some embodiments, one or more of the fluid
passageways 84a, 84c, or 84d are omitted from the flow block 64a,
and/or one or more fluid passageways analogous to the fluid
passageways 84a, 84c, or 84d of the flow block 64a are omitted from
the flow block 64b.
[0055] In an embodiment of the choke module 36, as illustrated in
FIGS. 4(a)-(f) with continuing reference to FIGS. 5(a)-(b), the
block valve 66a is operably coupled to the side 80c of the flow
block 64a and in fluid communication with the internal region 82
thereof via the fluid passageway 84e, and the block valve 66c is
operably coupled to the side 80c of the flow block 64a (adjacent
the block valve 66a) and in fluid communication with the internal
region 82 thereof via the fluid passageway 84f. The block valves
66b and 66d are operably coupled to the flow block 64b in
substantially the same manner as the manner in which the block
valves 66a and 66c are operably coupled to the flow block 64a. The
block valve 66e is operably coupled to the side 80b of the flow
block 64a and in fluid communication with the internal region 82
thereof via the fluid passageway 84d. Moreover, the block valve 66e
is operably coupled to the flow block 64b in substantially the same
manner as the manner in which the block valve 66e is operably
coupled to the flow block 64a, except that the block valve 66e is
operably coupled to a side of the flow block 64b analogous to the
side 80a of the flow block 64a--as a result, the block valve 66e is
in fluid communication with an internal region of the flow block
64b via a fluid passageway analogous to the fluid passageway 84c of
the flow block 64a.
[0056] In some embodiments, the operable coupling of the block
valves 66a and 66c to the flow block 64a and the operable coupling
of the block valves 66b and 66d to the flow block 64b reduce the
number of fluid couplings, and thus potential leak paths, required
to make up the choke module 36. In some embodiments, the manner in
which the block valves 66a and 66c are operably coupled to the flow
block 64a and the manner in which the block valves 66b and 66d are
operably coupled to the flow block 64b permit the drilling chokes
70a and 70b to be operably coupled in parallel between the flow
blocks 64a and 64b. In some embodiments, the spacing between the
block valves 66a and 66c operably coupled to the flow block 64a and
the spacing between the block valves 66b and 66d operably coupled
to the flow block 64b permit the drilling chokes 70a and 70b to be
operably coupled in parallel between the flow blocks 64a and
64b.
[0057] In an embodiment, as illustrated in FIGS. 4(a)-(f) with
continuing reference to FIGS. 2 and 3, an embodiment of the valve
module 40 is shown in which the valve module 40 includes flow
blocks 86a-b and valves 88a-e. The valves 88a-e are each actuable
between an open configuration in which fluid flow is permitted
therethrough, and a closed configuration in which fluid flow
therethrough is prevented, or at least reduced. In some
embodiments, the valves 88a-e are gate valves. Alternatively, one
or more of the valves 88a-e may be another type of valve such as,
for example, a plug valve. The valve 88e is operably coupled
between the flow blocks 86a and 86b. The valve 88a is operably
coupled to the flow block 86a. The valve 88b is operably coupled to
the flow block 86a, opposite the valve 88a. The valve 88c is
operably coupled to the flow block 86b. The valve 88d is operably
coupled to the flow block 86b, opposite the valve 88c.
[0058] The valve module 40 is actuable between a flow metering
configuration and a meter bypass configuration. In the flow
metering configuration, the flow blocks 86a and 86b are in fluid
communication via at least the valves 88b and 88d (e.g., the valves
88b and 88d are open) and the flow meter module 38, and are not in
fluid communication via the valve 88e (i.e., the valve 88e is
closed). In some embodiments, when the valve module 40 is in the
flow metering configuration, the valves 88a and 88e are closed and
the valves 88b-d are open. Alternatively, in some embodiments, when
the valve module is in the flow metering configuration, the valves
88c and 88e are closed and the valves 88a, 88b, and 88d are open.
In the meter bypass configuration, the flow blocks 86a and 86b are
in fluid communication via the valve 88e (i.e., the valve 88e is
open), and are not in fluid communication via the valves 88b and
88d (e.g., the valves 88b and 88d are closed) and the flow meter
module 38. In some embodiments, when the valve module 40 is in the
meter bypass configuration, the valves 88a, 88b, and 88d are closed
and the valves 88c and 88e are open. Alternatively, in some
embodiments, when the valve module 40 is in the meter bypass
configuration, the valves 88b-d are closed and the valves 88a and
88e are open.
[0059] In some embodiments, the flow blocks 86a and 86b are
substantially identical to one another and, therefore, in
connection with FIGS. 6(a)-(b), only the flow block 86a will be
described in detail below; however, the description below applies
to both of the flow blocks 86a and 86b. In an embodiment, as
illustrated in FIGS. 6(a)-(b) with continuing reference to FIGS.
4(a)-(f), the flow block 86a includes sides 90a-f. In some
embodiments, the sides 90a and 90b are spaced in a substantially
parallel relation. In some embodiments, the sides 90c and 90d are
spaced in a substantially parallel relation, each extending from
the side 90a to the side 90b. In some embodiments, the sides 90e
and 90f are spaced in a substantially parallel relation, each
extending from the side 90a to the side 90b. In some embodiments,
one of which is shown in FIGS. 6(a)-(b), the sides 90c and 90d are
spaced in a substantially parallel relation, and the sides 90e and
90f are spaced in a substantially parallel relation. In some
embodiments, the sides 90c and 90d are spaced in a substantially
perpendicular relation with the sides 90e and 90f. In some
embodiments, the sides 90a and 90b are spaced in a substantially
perpendicular relation with the sides 90c and 90d. In some
embodiments, the sides 90a and 90b are spaced in a substantially
perpendicular relation with the sides 90e and 90f. In some
embodiments, one of which is shown in FIGS. 6(a)-(b), the sides 90a
and 90b are spaced in a substantially perpendicular relation with
the sides 90c, 90d, 90e, and 90f.
[0060] In addition, the flow block 86a defines an internal region
92 and fluid passageways 94a-e. In some embodiments, the fluid
passageway 94a extends through the side 90a of the flow block 86a
into the internal region 92. In some embodiments, the fluid
passageway 94b extends through the side 90b of the flow block 86a
into the internal region 92. In some embodiments, one of which
shown in FIGS. 6(a)-(b), the fluid passageway 94a extends through
the side 90a of the flow block 86a into the internal region 92, and
the fluid passageway 94b extends through the side 90b of the flow
block 86a into the internal region 92. In some embodiments, the
fluid passageways 94a and 94b form a continuous fluid passageway
together with the internal region 92. In some embodiments, the
fluid passageway 94c extends through the side 90c of the flow block
86a into the internal region 92. In some embodiments, the fluid
passageway 94d extends through the side 90d of the flow block 86a
into the internal region 92. In some embodiments, one of which is
shown in FIGS. 6(a)-(b), the fluid passageway 94c extends through
the side 90c of the flow block 86a into the internal region 92, and
the fluid passageway 94d extends through the side 90d of the flow
block 86a into the internal region 92. In some embodiments, the
fluid passageways 94c and 94d form a continuous fluid passageway
together with the internal region 92. In some embodiments, one of
which is shown in FIGS. 6(a)-(b), the fluid passageway 94e extends
through the side 90e of the flow block 86a into the internal region
92.
[0061] In an embodiment of the valve module 40, as illustrated in
FIGS. 4(a)-(f) with continuing reference to FIGS. 6(a)-(b), the
valve 88a is operably coupled to the side 90a of the flow block 86a
and in fluid communication with the internal region 92 thereof via
the fluid passageway 94a, and the valve 88b is operably coupled to
the side 90b of the flow block 86a and in fluid communication with
the internal region 92 thereof via the fluid passageway 94b. In
some embodiments, a blind flange 95a is operably coupled to the
side 90e of the flow block 86a to prevent communication between the
internal region 92 and atmosphere via the fluid passageway 94e. The
valves 88c and 88d are operably coupled to the flow block 86b in
substantially the same manner as the manner in which the valves 88a
and 88b are operably coupled to the flow block 86a. In some
embodiments, a blind flange 95b is operably coupled to the flow
block 86b in substantially the same manner as the manner in which
the blind flange 95a is operably coupled to the flow block 86a. The
valve 88e is operably coupled to the side 90d of the flow block 86a
and in fluid communication with the internal region 92 thereof via
the fluid passageway 94d. Moreover, the valve 88e is operably
coupled to the flow block 86b in substantially the same manner as
the manner in which the valve 88e is operably coupled to the flow
block 86a, except that the valve 88e is operably coupled to a side
of the flow block 86b analogous to the side 90c of the flow block
86a--as a result, the valve 88e is in fluid communication with an
internal region of the flow block 86b via a fluid passageway
analogous to the fluid passageway 94c of the flow block 86a.
[0062] In an embodiment of the flow meter 38, as illustrated in
FIGS. 4(a)-(f) with continuing reference to FIGS. 2 and 3, an
embodiment of the flow meter module 38 is illustrated in which the
flow meter module 38 includes a flow meter 96, flow blocks 98a-b,
and spools 100a-b. In some embodiments, the flow meter 96 is a
Coriolis flow meter. The spool 100a is operably coupled to, and in
fluid communication with, the flow block 98a, and the flow meter 96
is operably coupled to, and in fluid communication with, the flow
block 98b. Alternatively, the spool 100a may be operably coupled
to, and in fluid communication with, the flow block 98b, and the
flow meter 96 may be operably coupled to, and in fluid
communication with, the flow block 98a. The spool 100b is operably
coupled between, and in fluid communication with, the flow blocks
98a and 98b. In some embodiments, a measurement fitting 102a is
operably coupled to the flow block 98a, opposite the spool 100a. In
addition to, or instead of, the measurement fitting 102a, a
measurement fitting 102b may be operably coupled to the flow block
98b, opposite the flow meter 96. In some embodiments, pressure
monitoring equipment 103 (shown in FIG. 4(f)) such as, for example,
electronic pressure monitoring equipment (including one or more
pressure sensors) for automatically controlling one or more of the
drilling chokes 70a and/or 70b, is operably coupled to one or both
of the measurement fittings 102a and 102b. Instead of, or in
addition to, the electronic pressure monitoring equipment, the
pressure monitoring equipment 103 may include analog pressure
monitoring equipment (including one or more pressure sensors),
which may be operably coupled to one or both of the measurement
fittings 102a and 102b.
[0063] When the MPD manifold 20 is assembled, the valve module 40
is operably coupled between the choke module 36 and the flow meter
module 38. More particularly, the valve 88a is operably coupled to
the end 78b of the flow block 64a and in fluid communication with
the internal region 82 thereof via the fluid passageway 84b, and
the valve 88c is operably coupled to the flow block 64b in
substantially the same manner as the manner in which the valve 88a
is operably coupled to the flow block 64a. In addition, the valve
88b is operably coupled to the spool 100a, opposite the flow block
98a, and the valve 88d is operably coupled to the flow meter 96,
opposite the flow block 98b. As a result, when the valve module 40
is operably coupled between the choke module 36 and the flow meter
module 38, as shown in FIGS. 4(a)-(f), the flow meter module 38
extends in a generally horizontal orientation. In those embodiments
in which the flow meter module 38 extends in the generally
horizontal orientation, the MPD manifold 20 is especially well
suited for use in onshore drilling operations. In some embodiments,
rather than the valve 88b being operably coupled to the spool 100a
and the valve 88d being operably coupled to the flow meter 96, the
valve 88b is operably coupled to the flow meter 96 and the valve
88d is operably coupled to the spool 100a.
[0064] In an embodiment, as illustrated in FIGS. 4(a)-(f), the MPD
manifold 20 further includes a flow fitting 104a operably coupled
to the side 90c of the flow block 86a and in fluid communication
with the internal region 92 thereof via the fluid passageway 94c,
and a flow fitting 104b operably coupled to the side 80a of the
flow block 64a and in fluid communication with the internal region
82 thereof via the fluid passageway 84c. In addition to, or instead
of, the flow fitting 104b, the MPD manifold 20 may include a flow
fitting 106a operably coupled to the flow block 64b in
substantially the same manner as the manner in which the flow
fitting 104b is operably coupled to the flow block 64a, except that
the flow fitting 106a is operably coupled to a side of the flow
block 64b analogous to the side 80b of the flow block 64a.
Moreover, in addition to, or instead of, the flow fitting 104a, the
MPD manifold 20 may include a flow fitting 106b operably coupled to
the flow block 86b in substantially the same manner as the manner
in which the flow fitting 104a is operably coupled to the flow
block 86a, except that the flow fitting 106b is operably coupled to
a side of the flow block 86b analogous to the side 90d of the flow
block 86a.
[0065] In those embodiments in which the MPD manifold 20 includes
the flow fittings 104a and 104b, the temperature sensor 48 and the
densometer 50 may be operably coupled to the valve module 40 (as
shown in FIG. 2) via the flow fitting 104a, and the temperature
sensor 44 and the densometer 46 may be operably coupled to the
choke module 36 (as shown in FIG. 2) via the flow fitting 104b. In
such embodiments, the flow fitting 104a is adapted to receive the
drilling mud from the RCD 16 and the MGS 22 is adapted to receive
the drilling mud from the flow fitting 104b. As a result, the
drilling mud may be permitted to flow through the flow meter 96
before flowing through the drilling chokes 70a and/or 70b.
Additionally, in those embodiments in which the MPD manifold 20
includes the flow fittings 106a and 106b, the temperature sensor 48
and the densometer 50 may be operably coupled to the choke module
36 (as shown in FIG. 3) via the flow fitting 106a, and the
temperature sensor 44 and the densometer 46 may be operably coupled
to the valve module 40 (as shown in FIG. 3) via the flow fitting
106b. In such embodiments, the flow fitting 106a is adapted to
receive the drilling mud from the RCD 16 and the MGS 22 is adapted
to receive the drilling mud from the flow fitting 106b, as
described in further detail below with reference to FIG. 3. As a
result, the drilling mud may be permitted to flow through the
drilling chokes 70a and/or 70b before flowing through the flow
meter 96.
[0066] In some embodiments, a measurement fitting 108 is operably
coupled to the flow block 64b and in fluid communication with an
internal region thereof via a fluid passageway analogous to the
fluid passageway 84a of the flow block 64a. In addition to, or
instead of, the measurement fitting 108, another measurement
fitting (not shown) may be operably coupled to the end 78a of the
flow block 64a and in fluid communication with the internal region
82 thereof via the fluid passageway 84a. In some embodiments,
pressure monitoring equipment 107 (shown in FIG. 4(a)) such as, for
example, electronic pressure monitoring equipment (including one or
more pressure sensors) for automatically controlling one or more of
the drilling chokes 70a and/or 70b, is operably coupled to the
measurement fitting 108 and/or the measurement fitting that is
operably coupled to the flow block 64a. In addition to, or instead
of, the electronic pressure monitoring equipment, the pressure
monitoring equipment 107 may include analog pressure monitoring
equipment (including one or more pressure sensors), which may be
operably coupled to the measurement fitting 108 and/or the
measurement fitting that is operably coupled to the flow block
64a.
[0067] In an embodiment, as illustrated in FIGS. 7(a)-(d) with
continuing reference to FIGS. 4(a)-(f), the valve module 40 is
configurable so that, rather than the valve 88b being operably
coupled to the side 90b of the flow block 86a and in fluid
communication with the internal region 92 thereof via the fluid
passageway 94b, the valve 88b is operably coupled to the side 90e
of the flow block 86a and in fluid communication with the internal
region 92 thereof via the fluid passageway 94e. In addition, the
valve 88d is operably coupled to the flow block 86b in
substantially the same manner as the manner in which the valve 88b
is operably coupled to the flow block 86a. As a result, when the
valve module 40 is operably coupled between the choke module 36 and
the flow meter module 38, as shown in FIGS. 7(a)-(d), the flow
meter module 38 extends in a generally vertical orientation, thus
significantly decreasing the overall footprint of the MPD manifold
20. In those embodiments in which the flow meter module 38 extends
in the generally vertical orientation, the MPD manifold 20 is
especially well suited for use in offshore drilling operations. In
some embodiments, the blind flange 95a is operably coupled to the
side 90b of the flow block 86a to prevent communication between the
internal region 92 and atmosphere via the fluid passageway 94b. In
some embodiments, the blind flange 95b is operably coupled to the
flow block 86b in substantially the same manner as the manner in
which the blind flange 95a is operably coupled to the flow block
86a.
[0068] In an embodiment, as illustrated in FIG. 3 with continuing
reference to FIG. 1, the MPD manifold 20 is configurable so that,
rather than being operably coupled to the choke module 36, the
temperature sensor 44 and the densometer 46 are operably coupled to
the valve module 40. Additionally, the MPD manifold 20 is
configurable so that, rather than being operably coupled to the
valve module 40, the temperature sensor 48 and the densometer 50
are operably coupled to the choke module 36. In some embodiments,
in addition to the choke module 36, the flow meter module 38, and
the valve module 40 being together mounted to the skid 42, one or
more of the temperature sensors 44 and 48, and the densometers 46
and 50 are also mounted to the skid 42. During the operation of the
drilling system 10, the choke module 36 receives drilling mud from
the RCD 16, as indicated by arrows 110 and 112. The temperature
sensor 48 measures the temperature of the drilling mud immediately
before the drilling mud is received by the choke module 36. In
addition, the densometer 50 measures the density of the drilling
mud immediately before the drilling mud is received by the choke
module 36. The choke module 36 is adjusted to maintain the desired
backpressure of the drilling mud within the wellbore 29. The choke
module 36 communicates the drilling mud to the valve module 40, as
indicated by arrow 114. The valve module 40 routes the drilling mud
from the choke module 36 to the flow meter module 38, as indicated
by arrow 116. The flow meter module 38 measures the flow rate of
the drilling mud before communicating the drilling mud back to the
valve module 40, as indicated by arrow 118. The MGS 22 receives the
drilling mud from the valve module 40, as indicated by arrows 120
and 122. The temperature sensor 44 measures the temperature of the
drilling mud immediately after the drilling mud is discharged from
the valve module 40. In addition, the densometer 46 measures the
density of the drilling mud immediately after the drilling mud is
discharged from the valve module 40.
[0069] In some embodiments, to determine the weight of the drilling
mud: the temperature of the drilling mud measured by the
temperature sensor 44 is compared with the temperature of the
drilling mud measured by the temperature sensor 48; the density of
the drilling mud measured by the densometer 46 is compared with the
density of the drilling mud measured by the densometer 50; and/or
the respective pressure(s) of the drilling mud measured by the
pressure monitoring equipment 103 (shown in FIG. 4(f)) operably
coupled to the measurement fittings 102a and 102b, the pressure
monitoring equipment 107 (shown in FIG. 4(a)) operably coupled to
the measurement fitting 108, pressure monitoring equipment operably
coupled to another measurement fitting of the MPD manifold 20, or
any combination thereof, are compared. Thus, the temperature
sensors 44 and 48, the densometers 46 and 50, and/or the pressure
monitoring equipment 103 and/or 107 are operable to determine
whether the weight of the drilling mud is below a critical
threshold. In some embodiments, in response to a determination that
the weight of the drilling mud is below the critical threshold: the
weight of the drilling fluid circulated to the drilling tool (as
indicated by the arrows 30 and 32 in FIG. 1) is increased, and/or
the drilling chokes 70a and/or 70b are adjusted to increase the
backpressure of the drilling mud within the wellbore 29. In this
manner, the temperature sensors 44 and 48, the densometers 46 and
50, and/or the pressure monitoring equipment 103 and/or 107 may be
used to predict and prevent well kicks during drilling
operations.
[0070] In some embodiments, to determine the amount of gas
entrained in the drilling mud: the temperature of the drilling mud
measured by the temperature sensor 44 is compared with the
temperature of the drilling mud measured by the temperature sensor
48; the density of the drilling mud measured by the densometer 46
is compared with the density of the drilling mud measured by the
densometer 50; and/or the respective pressure(s) of the drilling
mud measured by the pressure monitoring equipment 103, the pressure
monitoring equipment 107, pressure monitoring equipment operably
coupled to another measurement fitting of the MPD manifold 20, or
any combination thereof, are compared. Thus, the temperature
sensors 44 and 48, the densometers 46 and 50, and/or the pressure
monitoring equipment 103 and/or 107 are operable to determine
whether the amount of gas entrained in the drilling mud is above a
critical threshold. In some embodiments, in response to a
determination that the amount of gas entrained in the drilling mud
is above the critical threshold: the weight of the drilling fluid
circulated to the drilling tool (as indicated by the arrows 30 and
32 in FIG. 1) is increased, and/or the drilling chokes 70a and/or
70b are adjusted to increase the backpressure of the drilling mud
within the wellbore 29. In this manner, the temperature sensors 44
and 48, the densometers 46 and 50, and/or the pressure monitoring
equipment 103 and/or 107 may be used to predict and prevent well
kicks during drilling operations.
[0071] In some embodiments, the temperature and density of the
drilling mud measured before the drilling mud passes through the
drilling chokes 70a and/or 70b are compared with the temperature
and density of the drilling mud after the drilling mud passes
through the drilling chokes 70a and/or 70b. Further, in some
embodiments, the temperature and pressure of the drilling mud
measured before the drilling mud passes through the drilling chokes
70a and/or 70b are compared with the temperature and pressure of
the drilling mud measured after the drilling mud passes through the
drilling chokes 70a and/or 70b. Further still, in some embodiments,
the density and pressure of the drilling mud measured before the
drilling mud passes through the drilling chokes 70a and/or 70b are
compared with the density and pressure of the drilling mud measured
after the drilling mud passes through the drilling chokes 70a
and/or 70b. Finally, in some embodiments, the temperature, density,
and pressure of the drilling mud measured before the drilling mud
passes through the drilling chokes 70a and/or 70b are compared with
the temperature, density, and pressure of the drilling mud measured
after the drilling mud passes through the drilling chokes 70a
and/or 70b.
[0072] In some embodiments, during the operation of the MPD
manifold 20, the execution of the method 124, the execution of the
method 142, or any combination thereof, drilling mud is permitted
to flow through one of the drilling chokes 70a-b, and the one of
the drilling chokes 70a-b is controlled in accordance with the
foregoing; in some embodiments, the remaining one of the drilling
chokes 70a-b is closed but is nevertheless provided for redundancy
purposes such as, for example, in the event of operational problems
with one or both of the one of the drilling chokes 70a-b. In some
embodiments, during the operation of the MPD manifold 20, the
execution of the method 124, the execution of the method 142, or
any combination thereof, drilling mud is permitted to flow through
both of the drilling chokes 70a-b, and both of the drilling chokes
70a-b are controlled in accordance with the foregoing.
[0073] In an embodiment, as illustrated in FIG. 8, a method of
controlling backpressure of a drilling mud within a wellbore 29 is
diagrammatically illustrated and generally referred to by the
reference numeral 124. The method 124 includes receiving the
drilling mud from the wellbore 29 at a step 126; either:
controlling, using one or more of the drilling chokes 70a and 70b,
the backpressure of the drilling mud within the wellbore 29 at a
step 128, the drilling chokes 70a and 70b being part of the choke
module 36, or bypassing the drilling chokes 70a and 70b of the
choke module 36 at a step 131; either: measuring, using the flow
meter 96, a flow rate of the drilling mud received from the
wellbore 29 at a step 134, the flow meter 96 being part of the flow
meter module 38, or bypassing the flow meter 96 of the flow meter
module 38 at a step 136; and discharging the drilling mud at a step
138.
[0074] The drilling mud is received from the wellbore 29 at the
step 126. In an embodiment of the step 126, the drilling mud is
received from the wellbore 29 via the flow fitting 104a operably
coupled to, and in fluid communication with, the internal region 92
of the flow block 86a via the fluid passageway 94c thereof. In
another embodiment of the step 126, the drilling mud is received
from the wellbore 29 via the flow fitting 106a operably coupled to
the flow block 64b in substantially the same manner as the manner
in which the flow fitting 104b is operably coupled to the flow
block 64a, except that the flow fitting 106a is operably coupled to
a side of the flow block 64b analogous to the side 80b of the flow
block 64a.
[0075] In some embodiments, one or more of the drilling chokes 70a
and 70b control the backpressure of the drilling mud within the
wellbore 29 at the step 128. In an embodiment of the step 128, one
or more of the drilling chokes 70a and 70b are used to control the
backpressure of the drilling mud within the wellbore 29 by:
permitting fluid flow from the flow block 64b to the flow block 64a
via one or both of the following element combinations: the block
valve 66b, the drilling choke 70a, and the block valve 66a; the
block valve 66d, the drilling choke 70b, and the block valve 66c;
and preventing, or at least reducing, fluid flow from the flow
block 64b to the flow block 64a via the block valve 66e. More
particularly, one or more of the drilling chokes 70a and 70b may be
used to control the backpressure of the drilling mud within the
wellbore 29 by actuating the block valves 66a-e so that: the block
valves 66a-b are open and the block valves 66c-e are closed; the
block valves 66c-d are open and the block valves 66a-b and 66e are
closed; or the block valves 66a-d are open and the block valve 66e
is closed.
[0076] In some embodiments, the drilling chokes 70a and 70b are
bypassed at the step 131. In an embodiment of the step 131, the
drilling chokes 70a and 70b of the choke module 36 are bypassed by:
permitting fluid flow from the flow block 64b to the flow block 64a
via the block valve 66e; and preventing, or at least reducing,
fluid flow from the flow block 64b to the flow block 64a via each
of the following element combinations: the block valve 66b, the
drilling choke 70a, and the block valve 66a; and the block valve
66d, the drilling choke 70b, and the block valve 66c. More
particularly, the drilling chokes 70a and 70b of the choke module
36 are bypassed by actuating the block valves 66a-e so that: the
block valves 66a-d are closed and the block valve 66e is open.
[0077] In some embodiments, the flow meter 96 measures the flow
rate of the drilling mud received form the wellbore 29 at the step
134. In some embodiments, to measure the flow rate of the drilling
fluid at the step 134, the valve module 40 is used to communicate
the drilling mud to the flow meter module 38. In an embodiment, the
valve module 40 is used to communicate the drilling mud to the flow
meter module 38 by: permitting fluid flow from the flow block 86a
to the flow block 86b via the valve 88b, the flow meter 96, and the
valve 88d; and preventing, or at least reducing, fluid flow from
the flow block 86a to the flow block 86b via the valve 88e. More
particularly, the valve module 40 may be used to communicate the
drilling mud to the flow meter module 38 by actuating the valves
88a-e so that either: the valves 88b-d are open and the valves 88a
and 88e are closed; or the valves 88a, 88b, and 88d are open and
the valves 88c and 88e are closed.
[0078] In an embodiment of the step 134, the drilling mud flows
from the valve 88b, through the spool 100a, the flow block 98a, the
spool 100b, the flow block 98b, and the flow meter 96, and into the
valve 88d. During the flow of the drilling mud through the flow
meter 96, the flow meter 96 measures the flow rate of the drilling
mud. In some embodiments, the flow meter 96 is a Coriolis flow
meter.
[0079] In some embodiments, the flow meter 96 of the flow meter
module 38 is bypassed at the step 136. In an embodiment of the step
136, the flow meter 96 of the flow meter module 38 is bypassed by
preventing, or at least reducing, fluid flow from the flow block
86a to the flow block 86b via the valve 88b, the flow meter 96, and
the valve 88d; and permitting fluid flow from the flow block 86a to
the flow block 86b via the valve 88e. More particularly, the flow
meter 96 of the flow meter module 38 may be bypassed by actuating
the block valves 88a-e so that either: the valves 88c and 88e are
open and the valves 88a, 88b, and 88d are closed; or the valves 88a
and 88e are open and the valves 88b-d are closed.
[0080] The method 124 includes discharging the drilling mud at the
step 138. In an embodiment of the step 138, the drilling mud is
discharged via either: the flow fitting 104b operably coupled to,
and in fluid communication with, the internal region 82 of the flow
block 64a via the fluid passageway 84c thereof; or the flow fitting
106b operably coupled to the flow block 86b in substantially the
same manner as the manner in which the flow fitting 104a is
operably coupled to the flow block 86a, except that the flow
fitting 106b is operably coupled to a side of the flow block 86b
analogous to the side 90d of the flow block 86a.
[0081] In an embodiment of the steps 126 and 138, at the step 126
the drilling mud is received from the wellbore 29 via the flow
fitting 104a operably coupled to, and in fluid communication with,
the internal region 92 of the flow block 86a via the fluid
passageway 94c thereof, and at the step 138 the drilling mud is
discharged via the flow fitting 104b operably coupled to, and in
fluid communication with, the internal region 82 of the flow block
64a via the fluid passageway 84c thereof. In another embodiment of
the steps 126 and 138, at the step 126 the drilling mud is received
from the wellbore 29 via the flow fitting 106a operably coupled to
the flow block 64b in substantially the same manner as the manner
in which the flow fitting 104b is operably coupled to the flow
block 64a, and at the step 138 the drilling mud is discharged via
the flow fitting 106b operably coupled to the flow block 86b in
substantially the same manner as the manner in which the flow
fitting 104a is operably coupled to the flow block 86a.
[0082] In various embodiments, the steps of the method 124 may be
executed with different combinations of steps in different orders
and/or ways. For example, an embodiment of the method 124 includes:
the step 126 at which drilling mud is received from the wellbore 29
via the flow fitting 104a operably coupled to, and in fluid
communication with, the internal region 92 of the flow block 86a
via the fluid passageway 94c thereof; during and/or after the step
126, the step 134 at which the drilling mud flows from the flow
block 86a to the flow block 86b via the valve 88b, the spool 100a,
the flow block 98a, the spool 100b, the flow block 98b, the flow
meter 96, and the valve 88d (the valves 88a and 88e are closed);
during and/or after the step 134, the step 128 at which the
drilling mud flows from the flow block 86b to the flow block 64b
via the valve 88c, and from the flow block 64b to the flow block
64a via one or more of the following element combinations: the
block valve 66b, the drilling choke 70a, and the block valve 66a;
and the block valve 66d, the drilling choke 70b, and the block
valve 66c (the block valve 66e is closed); and during and/or after
the step 128, the step 138 at which the drilling mud is discharged
via the flow fitting 104b operably coupled to, and in fluid
communication with, the internal region 82 of the flow block 64a
via the fluid passageway 84c thereof.
[0083] For another example, an embodiment of the method 124
includes: the step 126 at which drilling mud is received from the
wellbore 29 via the flow fitting 104a operably coupled to, and in
fluid communication with, the internal region 92 of the flow block
86a via the fluid passageway 94c thereof; during and/or after the
step 126, the step 136 at which the drilling mud flows from the
flow block 86a to the flow block 86b via the valve 88e (the valves
88a-d are closed); during and/or after the step 136, the step 128
at which the drilling mud flows from the flow block 86b to the flow
block 64b via the valve 88c, and from the flow block 64b to the
flow block 64a via one or more of the following element
combinations: the block valve 66b, the drilling choke 70a, and the
block valve 66a; and the block valve 66d, the drilling choke 70b,
and the block valve 66c (the block valve 66e is closed); and during
and/or after the step 128, the step 138 at which the drilling mud
is discharged via the flow fitting 104b operably coupled to, and in
fluid communication with, the internal region 82 of the flow block
64a via the fluid passageway 84c thereof.
[0084] For yet another example, an embodiment of the method 124
includes: the step 126 at which drilling mud is received from the
wellbore 29 via the flow fitting 104a operably coupled to, and in
fluid communication with, the internal region 92 of the flow block
86a via the fluid passageway 94c thereof; during and/or after the
step 126, the step 134 at which the drilling mud flows from the
flow block 86a to the flow block 86b via the valve 88b, the spool
100a, the flow block 98a, the spool 100b, the flow block 98b, the
flow meter 96, and the valve 88d (the valves 88a and 88e are
closed); during and/or after the step 134, the step 131 at which
the drilling mud flows from the flow block 86b to the flow block
64b via the valve 88c, and from the flow block 64b to the flow
block 64a via the block valve 66e (the block valves 66a-d are
closed); and during and/or after the step 131, the step 138 at
which the drilling mud is discharged via the flow fitting 104b
operably coupled to, and in fluid communication with, the internal
region 82 of the flow block 64a via the fluid passageway 84c
thereof.
[0085] For yet another example, an embodiment of the method 124
includes: the step 126 at which drilling mud is received from the
wellbore 29 via the flow fitting 104a operably coupled to, and in
fluid communication with, the internal region 92 of the flow block
86a via the fluid passageway 94c thereof; during and/or after the
step 126, the step 136 at which the drilling mud flows from the
flow block 86a to the flow block 86b via the valve 88e (the valves
88a-d are closed); during and/or after the step 136, the step 131
at which the drilling mud flows from the flow block 86b to the flow
block 64b via the valve 88c, and from the flow block 64b to the
flow block 64a via the block valve 66e (the block valves 66a-d are
closed); and during and/or after the step 131, the step 138 at
which the drilling mud is discharged via the flow fitting 104b
operably coupled to, and in fluid communication with, the internal
region 82 of the flow block 64a via the fluid passageway 84c
thereof.
[0086] For yet another example, an embodiment of the method 124
includes: the step 126 at which the drilling mud is received from
the wellbore 29 via the flow fitting 106a operably coupled to the
flow block 64b in substantially the same manner as the manner in
which the flow fitting 104b is operably coupled to the flow block
64a; during and/or after the step 126, the step 128 at which the
drilling mud flows from the flow block 64b to the flow block 64a
via one or more of the following element combinations: the block
valve 66b, the drilling choke 70a, and the block valve 66a; and the
block valve 66d, the drilling choke 70b, and the block valve 66c
(the block valve 66e is closed); during and/or after the step 128,
the step 134 at which the drilling mud flows from the flow block
64a to the flow block 86a via the valve 88a, and from the flow
block 86a to the flow block 86b via the valve 88b, the spool 100a,
the flow block 98a, the spool 100b, the flow block 98b, the flow
meter 96, and the valve 88d (the valves 88c and 88e are closed);
and during and/or after the step 134, the step 138 at which the
drilling mud is discharged via the flow fitting 106b operably
coupled to the flow block 86b in substantially the same manner as
the manner in which the flow fitting 104a is operably coupled to
the flow block 86a.
[0087] For yet another example, an embodiment of the method 124
includes: the step 126 at which the drilling mud is received from
the wellbore 29 via the flow fitting 106a operably coupled to the
flow block 64b in substantially the same manner as the manner in
which the flow fitting 104b is operably coupled to the flow block
64a; during and/or after the step 126, the step 128 at which the
drilling mud flows from the flow block 64b to the flow block 64a
via one or more of the following element combinations: the block
valve 66b, the drilling choke 70a, and the block valve 66a; and the
block valve 66d, the drilling choke 70b, and the block valve 66c
(the block valve 66e is closed); during and/or after the step 128,
the step 136 at which the drilling mud flows from the flow block
64a to the flow block 86a via the valve 88a, and from the flow
block 86a to the flow block 86b via the valve 88e (the valves 88b-d
are closed); and during and/or after the step 136, the step 138 at
which the drilling mud is discharged via the flow fitting 106b
operably coupled to the flow block 86b in substantially the same
manner as the manner in which the flow fitting 104a is operably
coupled to the flow block 86a.
[0088] For yet another example, an embodiment of the method 124
includes: the step 126 at which the drilling mud is received from
the wellbore 29 via the flow fitting 106a operably coupled to the
flow block 64b in substantially the same manner as the manner in
which the flow fitting 104b is operably coupled to the flow block
64a; during and/or after the step 126, the step 131 at which the
drilling mud flows from the flow block 64b to the flow block 64a
via the block valve 66e (the block valves 66a-d are closed); during
and/or after the step 131, the step 134 at which the drilling mud
flows from the flow block 64a to the flow block 86a via the valve
88a, and from the flow block 86a to the flow block 86b via the
valve 88b, the spool 100a, the flow block 98a, the spool 100b, the
flow block 98b, the flow meter 96, and the valve 88d (the valves
88c and 88e are closed); and during and/or after the step 134, the
step 138 at which the drilling mud is discharged via the flow
fitting 106b operably coupled to the flow block 86b in
substantially the same manner as the manner in which the flow
fitting 104a is operably coupled to the flow block 86a.
[0089] Finally, for yet another example, an embodiment of the
method 124 includes: the step 126 at which the drilling mud is
received from the wellbore 29 via the flow fitting 106a operably
coupled to the flow block 64b in substantially the same manner as
the manner in which the flow fitting 104b is operably coupled to
the flow block 64a; during and/or after the step 126, the step 131
at which the drilling mud flows from the flow block 64b to the flow
block 64a via the block valve 66e (the block valves 66a-d are
closed); during and/or after the step 131, the step 136 at which
the drilling mud flows from the flow block 64a to the flow block
86a via the valve 88a, and from the flow block 86a to the flow
block 86b via the valve 88e (the valves 88b-d are closed); and
during and/or after the step 136, the step 138 at which the
drilling mud is discharged via the flow fitting 106b operably
coupled to the flow block 86b in substantially the same manner as
the manner in which the flow fitting 104a is operably coupled to
the flow block 86a.
[0090] In some embodiments, the configuration of the MPD manifold
20, including the drilling chokes 70a and 70b and the flow meter 96
used to carry out the method 124, optimizes the efficiency of the
drilling system 10, thereby improving the cost and effectiveness of
drilling operations. Such improved efficiency benefits operators
dealing with challenges such as, for example, continuous duty
operations, harsh downhole environments, and multiple
extended-reach lateral wells, among others. In some embodiments,
the configuration of the MPD manifold 20, including the drilling
chokes 70a and 70b and the flow meter 96 used to carry out the
method 124, favorably affects the size and/or weight of the MPD
manifold 20, and thus the transportability and overall footprint of
the MPD manifold 20 at the wellsite.
[0091] In some embodiments, the integrated nature of the drilling
chokes 70a and 70b and the flow meter 96 on the MPD manifold 20
used to carry out the method 124 makes it easier to inspect,
service, or repair the MPD manifold 20, thereby decreasing downtime
during drilling operations. In some embodiments, the integrated
nature of the drilling chokes 70a and 70b and the flow meter 96 on
the MPD manifold 20 used to carry out the method 124 makes it
easier to coordinate the inspection, service, repair, or
replacement of components of the MPD manifold 20 such as, for
example, the drilling chokes 70a and 70b and/or the flow meter 96,
among other components.
[0092] In this regard, an arrow 140 in FIGS. 4(b), 4(d), 7(b), and
7(c) indicates the direction in which the drilling choke 70a is
readily removable from the choke module 36 upon decoupling of the
spools 72a and 74a from the block valves 66a and 66b, respectively,
or decoupling of the flow block 68a and the drilling choke 70a from
the spools 72a and 74a, respectively. Further, the arrow 140
indicates the direction in which the drilling choke 70b is readily
removable from the choke module 36 upon decoupling of the spools
72b and 74b from the block valves 66c and 66d, respectively, or
decoupling of the flow block 68b and the drilling choke 70b from
the spools 72b and 74b, respectively. Thus, either one of the
drilling chokes 70a and 70b may be readily inspected, serviced,
repaired, or replaced during drilling operations while the other of
the drilling chokes 70a and 70b remains in service.
[0093] In an embodiment, as illustrated in FIG. 9, a method of
controlling backpressure of a drilling mud within a wellbore 29 is
diagrammatically illustrated and generally referred to by the
reference numeral 142. The method 142 includes receiving the
drilling mud from the wellbore 29 at a step 144; measuring, using a
first sensor, a first physical property of the drilling mud before
the drilling mud flows through the drilling chokes 70a and/or 70b
at a step 146; flowing the drilling mud through the drilling chokes
70a and/or 70b at a step 148; measuring, using a second sensor, the
first physical property of the drilling mud after the drilling mud
flows through the drilling chokes 70a and/or 70b at a step 150;
comparing the respective measurements of the first physical
property taken by the first and second sensors at a step 152;
determining, based on at least the comparison of the respective
measurements of the first physical property taken by the first and
second sensors, an amount of gas entrained in the drilling mud at a
step 154; and adjusting the drilling chokes 70a and/or 70b, based
on the determination of the amount of gas entrained in the drilling
mud, to control the backpressure of the drilling mud within the
wellbore 29 at a step 156. In some embodiments, when the amount of
gas entrained in the drilling mud is above a critical threshold,
the drilling chokes 70a and/or 70b are adjusted to increase the
backpressure of the drilling mud within the wellbore 29. In some
embodiments, in addition to, or instead of, determining the amount
of gas entrained in the drilling mud, the step 154 includes
determining, based on at least the comparison of the respective
measurements of the first physical property taken by the first and
second sensors, the weight of the drilling mud. As a result, the
step 156 includes adjusting the drilling chokes 70a and/or 70b,
based on the determination of the weight of the drilling mud, to
control the backpressure of the drilling mud within the wellbore
29.
[0094] In an embodiment of the steps 146, 148, and 150, the first
physical property is density and the first and second sensors are
the densometers 46 and 50. In another embodiment of the steps 146,
148, and 150, the first physical property is temperature and the
first and second sensors are the temperature sensors 44 and 48. In
yet another embodiment of the steps 146, 148, and 150, the first
physical property is pressure and the first and second sensors are
pressure sensors operably coupled to the measurement fittings 102a,
102b, 108, and/or another measurement fitting; in some embodiments,
these pressure sensors may be, may include, or may be a part of,
the pressure monitoring equipment 103 and/or 107.
[0095] In some embodiments of the method 142, the steps 146, 148,
and 150 further include measuring, using a third sensor, a second
physical property of the drilling mud before the drilling mud flows
through the drilling chokes 70a and/or 70b, measuring, using a
fourth sensor, the second physical property of the drilling mud
after the drilling mud flows through the drilling chokes 70a and/or
70b, and comparing the respective measurements of the second
physical property taken by the third and fourth sensors. In some
embodiments, determining the amount of gas entrained in the
drilling mud is further based on the comparison of the respective
measurements of the second physical property taken by the third and
fourth sensors. In an embodiment, the first physical property is
density and the first and second sensors are the densometers 46 and
50, and the second physical property is temperature and the third
and fourth sensors are the temperature sensors 44 and 48. In
another embodiment, the first physical property is density and the
first and second sensors are the densometers 46 and 50, and the
second physical property is pressure and the third and fourth
sensors are pressure sensors operably coupled to the measurement
fittings 102a, 102b, 108, and/or another measurement fitting; in
some embodiments, these pressure sensors may be, may include, or
may be a part of, the pressure monitoring equipment 103 and/or 107.
In yet another embodiment, the first physical property is
temperature and the first and second sensors are the temperature
sensors 44 and 48, and the second physical property is pressure and
the third and fourth sensors are pressure sensors operably coupled
to the measurement fittings 102a, 102b, 108, and/or another
measurement fitting; in some embodiments, these pressure sensors
may be, may include, or may be a part of, the pressure monitoring
equipment 103 and/or 107.
[0096] In some embodiments of the method 142, the steps 146, 148,
and 150 further include measuring, using a fifth sensor, a third
physical property of the drilling mud before the drilling mud flows
through the drilling chokes 70a and/or 70b, measuring, using a
sixth sensor, the third physical property of the drilling mud after
the drilling mud flows through the drilling chokes 70a and/or 70b,
and comparing the respective measurements of the third physical
property taken by the fifth and sixth sensors. In some embodiments,
determining the amount of gas entrained in the drilling mud is
further based on the comparison of the respective measurements of
the third physical property taken by the fifth and sixth sensors.
In an embodiment, the first physical property is density and the
first and second sensors are densometers 46 and 50, the second
physical property is temperature and the third and fourth sensors
are the temperature sensors 44 and 48, and the third physical
property is pressure and the fifth and sixth sensors are pressure
sensors operably coupled to the measurement fittings 102a, 102b,
108, and/or another measurement fitting; in some embodiments, these
pressure sensors may be, may include, or may be a part of, the
pressure monitoring equipment 103 and/or 107.
[0097] In an embodiment, as illustrated in FIGS. 10(a)-(f), the
choke module 36 is omitted from MPD manifold 20 and replaced with a
choke module 158--the ability of the choke module 36 to be easily
replaced by, or substituted with, the choke module 158 (or vice
versa) is denoted in FIGS. 2 and 3. The choke module 158 includes
flow blocks 160a-b, block valves 162a-m, bleed valves 163a-f, flow
blocks 164a-c, and drilling chokes 166a-c. The block valves 162a-m
are each actuable between an open configuration in which fluid flow
is permitted therethrough, and a closed configuration in which
fluid flow therethrough is prevented, or at least reduced. In some
embodiments, the block valves 162a-m are gate valves.
Alternatively, one or more of the block valves 162a-m may be
another type of valve such as, for example, a plug valve. The block
valve 162m is operably coupled between the flow blocks 160a and
160b.
[0098] The block valve 162a is operably coupled to the flow block
160a. The bleed valve 163a is operably coupled to the block valve
162a, opposite the flow block 160a. The block valve 162b is
operably coupled to the bleed valve 163a, opposite the block valve
162a. The flow block 164a is operably coupled to the block valve
162b, opposite the bleed valve 163a, via, for example, a spool
168a. In combination, the bleed valve 163a and the block valves
162a and 162b may provide a type of "double block-and-bleed"
isolation of the flow block 164a from the flow block 160a. For
example, in some embodiments, to provide a type of "double
block-and-bleed" isolation of the flow block 164a from the flow
block 160a, both of the block valves 162a and 162b are closed, and
the bleed valve 163a is opened to permit any necessary bleeding or
depressurization of the fluid flow path between the block valves
162a and 162b, ensuring that the flow block 164a has been
fluidically isolated from the flow block 160a. In some embodiments,
in combination, the bleed valve 163a and the block valves 162a and
162b provide a type of "double block-and-bleed" isolation of the
flow block 164a from the flow block 160a and therefore, in some
embodiments, this combination is especially suitable for offshore
applications. The block valve 162c is operably coupled to the flow
block 160b. The bleed valve 163b is operably coupled to the block
valve 162c, opposite the flow block 160b. The block valve 162d is
operably coupled to the bleed valve 163b, opposite the block valve
162c. The drilling choke 166a is operably coupled to the block
valve 162d, opposite the bleed valve 163b, via, for example, a
spool 170a. In combination, the bleed valve 163b and the block
valves 162c and 162d may provide a type of "double block-and-bleed"
isolation of the drilling choke 166a from the flow block 160b. For
example, in some embodiments, to provide a type of "double
block-and-bleed" isolation of the drilling choke 166a from the flow
block 160b, both of the block valves 162c and 162d are closed, and
the bleed valve 163b is opened to permit any necessary bleeding or
depressurization of the fluid flow path between the block valves
162c and 162d, ensuring that the drilling choke 166a has been
fluidically isolated from the flow block 160b. In some embodiments,
in combination, the bleed valve 163b and the block valves 162c and
162d provide a type of "double block-and-bleed" isolation of the
drilling choke 166a from the flow block 160b and therefore, in some
embodiments, this combination is especially suitable for offshore
applications. The drilling choke 166a is operably coupled to the
flow block 164a via, for example, a spool 172a.
[0099] The block valve 162e is operably coupled to the flow block
160a adjacent the block valve 162a. The bleed valve 163c is
operably coupled to the block valve 162e, opposite the flow block
160a. The block valve 162f is operably coupled to the bleed valve
163c, opposite the block valve 162e. The flow block 164b is
operably coupled to the block valve 162f, opposite the bleed valve
163c, via, for example, a spool 168b. In combination, the bleed
valve 163c and the block valves 162e and 162f may provide a type of
"double block-and-bleed" isolation of the flow block 164b from the
flow block 160a. For example, in some embodiments, to provide a
type of "double block-and-bleed" isolation of the flow block 164b
from the flow block 160a, both of the block valves 162e and 162f
are closed, and the bleed valve 163c is opened to permit any
necessary bleeding or depressurization of the fluid flow path
between the block valves 162e and 162f, ensuring that the flow
block 164b has been fluidically isolated from the flow block 160a.
In some embodiments, in combination, the bleed valve 163c and the
block valves 162e and 162f provide a type of "double
block-and-bleed" isolation of the flow block 164b from the flow
block 160a and therefore, in some embodiments, this combination is
especially suitable for offshore applications. The block valve 162g
is operably coupled to the flow block 160b adjacent the block valve
162c. The bleed valve 163d is operably coupled to the block valve
162g, opposite the flow block 160b. The block valve 162h is
operably coupled to the bleed valve 163d, opposite the block valve
162g. The drilling choke 166b is operably coupled to the block
valve 162h, opposite the bleed valve 163d, via, for example, a
spool 170b. In combination, the bleed valve 163d and the block
valves 162g and 162h may provide a type of "double block-and-bleed"
isolation of the drilling choke 166b from the flow block 160b. For
example, in some embodiments, to provide a type of "double
block-and-bleed" isolation of the drilling choke 166b from the flow
block 160b, both of the block valves 162g and 162h are closed, and
the bleed valve 163d is opened to permit any necessary bleeding or
depressurization of the fluid flow path between the block valves
162g and 162h, ensuring that the drilling choke 166b has been
fluidically isolated from the flow block 160b. In some embodiments,
in combination, the bleed valve 163d and the block valves 162g and
162h provide a type of "double block-and-bleed" isolation of the
drilling choke 166b from the flow block 160b and therefore, in some
embodiments, this combination is especially suitable for offshore
applications. The drilling choke 166b is operably coupled to the
flow block 164b via, for example, a spool 172b.
[0100] The block valve 162i is operably coupled to the flow block
160a adjacent the block valve 162e. The bleed valve 163e is
operably coupled to the block valve 162i, opposite the flow block
160a. The block valve 162j is operably coupled to the bleed valve
163e, opposite the block valve 162i. The flow block 164c is
operably coupled to the block valve 162j, opposite the bleed valve
163e, via, for example, a spool 168c. In combination, the bleed
valve 163e and the block valves 162i and 162j may provide a type of
"double block-and-bleed" isolation of the flow block 164c from the
flow block 160a. For example, in some embodiments, to provide a
type of "double block-and-bleed" isolation of the flow block 164c
from the flow block 160a, both of the block valves 162i and 162j
are closed, and the bleed valve 163e is opened to permit any
necessary bleeding or depressurization of the fluid flow path
between the block valves 162i and 162j, ensuring that the flow
block 164c has been fluidically isolated from the flow block 160a.
In some embodiments, in combination, the bleed valve 163e and the
block valves 162i and 162j provide a type of "double
block-and-bleed" isolation of the flow block 164c from the flow
block 160a and therefore, in some embodiments, this combination is
especially suitable for offshore applications. The block valve 162k
is operably coupled to the flow block 160b adjacent the block valve
162g. The bleed valve 163f is operably coupled to the block valve
162k, opposite the flow block 160b. The block valve 162l is
operably coupled to the bleed valve 163f, opposite the block valve
162k. The drilling choke 166c is operably coupled to the block
valve 162l, opposite the bleed valve 163f, via, for example, a
spool 170c. In combination, the bleed valve 163f and the block
valves 162k and 162l may provide a type of "double block-and-bleed"
isolation of the drilling choke 166c from the flow block 160b. For
example, in some embodiments, to provide a type of "double
block-and-bleed" isolation of the drilling choke 166c from the flow
block 160b, both of the block valves 162k and 162l are closed, and
the bleed valve 163f is opened to permit any necessary bleeding or
depressurization of the fluid flow path between the block valves
162k and 162l, ensuring that the drilling choke 166c has been
fluidically isolated from the flow block 160b. In some embodiments,
in combination, the bleed valve 163f and the block valves 162k and
162l provide a type of "double block-and-bleed" isolation of the
drilling choke 166c from the flow block 160b and therefore, in some
embodiments, this combination is especially suitable for offshore
applications. The drilling choke 166c is operably coupled to the
flow block 164c via, for example, a spool 172c.
[0101] In some embodiments, each of the bleed valves 163a-f is,
includes, or is part of, a needle valve. In some embodiments, at
least one of the bleed valves 163a-f is, includes, or is part of, a
needle valve. In some embodiments, one or more of the bleed valves
163a-f is, includes, or is part of, a needle valve. In some
embodiments, each of the drilling chokes 166a-c is a 4-inch inner
diameter (ID) choke. In some embodiments, each of the drilling
chokes 166a-c defines an inner diameter of about 4 inches.
[0102] The choke module 158 is actuable between a backpressure
control configuration and a choke bypass configuration. In the
backpressure control configuration, the flow block 160b is in fluid
communication with the flow block 160a via one or more of the
drilling chokes 166a, 166b, and/or 166c. In some embodiments, when
the choke module 158 is in the backpressure control configuration,
the flow block 160b is not in fluid communication with the flow
block 160a via the block valve 162m (i.e., the block valve 162m is
closed). During the operation of the drilling system 10, when the
choke module 158 is in the backpressure control configuration, one
or more of the drilling chokes 166a, 166b, and/or 166c are adjusted
to account for changes in the flow rate of the drilling mud so that
the desired backpressure within the wellbore 29 is maintained. In
the choke bypass configuration, the flow block 160b is in fluid
communication with the flow block 160a via the block valve 162m. In
some embodiments, when the choke module 158 is in the choke bypass
configuration, the flow block 160b is not in fluid communication
with the flow block 160a via the drilling chokes 166a, 166b, or
166c. In some embodiments, to enable such fluid communication
between the flow blocks 160a and 160b via the block valve 162m, the
block valves 162a-1 are actuated to the closed configuration and
the block valve 162m is actuated to the open configuration.
[0103] In some embodiments, one or more of the drilling chokes
166a, 166b, and/or 166c are manual chokes, thus enabling rig
personnel to manually control backpressure within the drilling
system 10 when the choke module 158 is in the backpressure control
configuration. In some embodiments, one or more of the drilling
chokes 166a, 166b, and/or 166c are automatic chokes controlled
automatically by electronic pressure monitoring equipment when the
choke module 158 is in the backpressure control configuration. In
some embodiments, one or more of the drilling chokes 166a, 166b,
and/or 166c are combination manual/automatic chokes.
[0104] In some embodiments, when the choke module 158 is in the
backpressure control configuration, the flow block 160b is in fluid
communication with the flow block 160a via at least the drilling
choke 166a. To enable such fluid communication between the flow
blocks 160a and 160b via the drilling choke 166a, the block valves
162a, 162b, 162c, and 162d are actuated to the open configuration,
and the block valve 162m is actuated to the closed configuration.
As a result, the flow block 160b is in fluid communication with the
flow block 160a via at least the block valve 162c, the bleed valve
163a, the block valve 162d, the spool 170a, the drilling choke
166a, the spool 172a, the flow block 164a, the spool 168a, the
block valve 162b, the bleed valve 163a, and the block valve 162a,
respectively.
[0105] In some embodiments, when the choke module 158 is in the
backpressure control configuration, the flow block 160b is in fluid
communication with the flow block 160a via at least the drilling
choke 166b. To enable such fluid communication between the flow
blocks 160a and 160b via the drilling choke 166b, the block valves
162e, 162f, 162g, and 162h are actuated to the open configuration,
and the block valve 162m is actuated to the closed configuration.
As a result, the flow block 160b is in fluid communication with the
flow block 160a via at least the block valve 162g, the bleed valve
163d, the block valve 162h, the spool 170b, the drilling choke
166b, the spool 172b, the flow block 164b, the spool 168b, the
block valve 162f, the bleed valve 163c, and the block valve 162e,
respectively.
[0106] In some embodiments, when the choke module 158 is in the
backpressure control configuration, the flow block 160b is in fluid
communication with the flow block 160a via at least the drilling
choke 166c. To enable such fluid communication between the flow
blocks 160a and 160b via the drilling choke 166c, the block valves
162i, 162j, 162k, and 162l are actuated to the open configuration,
and the block valve 162m is actuated to the closed configuration.
As a result, the flow block 160b is in fluid communication with the
flow block 160a via at least the block valve 162l, the bleed valve
163f, the block valve 162l, the spool 170c, the drilling choke
166c, the spool 172c, the flow block 164c, the spool 168c, the
block valve 162j, the bleed valve 163e, and the block valve 162i,
respectively.
[0107] In some embodiments, the flow blocks 160a and 160b are
substantially identical to one another and, therefore, in
connection with FIGS. 11(a)-(b), only the flow block 160a will be
described in detail below; however, the description below applies
to both of the flow blocks 160a and 160b. In an embodiment, as
illustrated in FIGS. 11(a)-(b) with continuing reference to FIGS.
10(a)-(f), the flow block 160a includes ends 174a-b and sides
176a-d. In some embodiments, the ends 174a and 174b are spaced in a
substantially parallel relation. In some embodiments, the sides
176a and 176b are spaced in a substantially parallel relation, each
extending from the end 174a to the end 174b. In some embodiments,
the sides 176c and 176d are spaced in a substantially parallel
relation, each extending from the end 174a to the end 174b. In some
embodiments, one of which is shown in FIGS. 11(a)-(b), the sides
176a and 176b are spaced in a substantially parallel relation, and
the sides 176c and 176d are spaced in a substantially parallel
relation. In some embodiments, the sides 176a and 176b are spaced
in a substantially perpendicular relation with the sides 176c and
176d. In some embodiments, the ends 174a and 174b are spaced in a
substantially perpendicular relation with the sides 176a and 176b.
In some embodiments, the ends 174a and 174b are spaced in a
substantially perpendicular relation with the sides 176c and 176d.
In some embodiments, one of which is shown in FIGS. 11(a)-(b), the
ends 174a and 174b are spaced in a substantially perpendicular
relation with the sides 176a, 176b, 176c, and 176d.
[0108] In addition, the flow block 160a defines an internal region
178 and fluid passageways 180a-g. In some embodiments, the fluid
passageway 180a extends through the end 174a of the flow block 160a
into the internal region 178. In some embodiments, the fluid
passageway 180b extends through the end 174b of the flow block 160a
into the internal region 178. In some embodiments, one of which
shown in FIGS. 11(a)-(b), the fluid passageway 180a extends through
the end 174a of the flow block 160a into the internal region 178,
and the fluid passageway 180b extends through the end 174b of the
flow block 160a into the internal region 178. In some embodiments,
the fluid passageways 180a and 180b form a continuous fluid
passageway together with the internal region 178. In some
embodiments, the fluid passageway 180c extends through the side
176a of the flow block 160a into the internal region 178. In some
embodiments, the fluid passageway 180d extends through the side
176b of the flow block 160a into the internal region 178. In some
embodiments, one of which is shown in FIGS. 11(a)-(b), the fluid
passageway 180c extends through the side 176a of the flow block
160a into the internal region 178, and the fluid passageway 180d
extends through the side 176b of the flow block 160a into the
internal region 178. In some embodiments, the fluid passageways
180c and 180d form a continuous fluid passageway together with the
internal region 178. In some embodiments, one of which is shown in
FIGS. 11(a)-(b), the fluid passageways 180e, 180f, and 180g each
extend through the side 176c of the flow block 160a into the
internal region 178. In some embodiments, one or more of the fluid
passageways 180a, 180c, or 180d are omitted from the flow block
160a, and/or one or more fluid passageways analogous to the fluid
passageways 180a, 180c, or 180d of the flow block 160a are omitted
from the flow block 160b.
[0109] In an embodiment of the choke module 158, as illustrated in
FIGS. 10(a)-(f) with continuing reference to FIGS. 11(a)-(b), it
can be seen that the block valve 162a is operably coupled to the
side 176c of the flow block 160a and in fluid communication with
the internal region 178 thereof via the fluid passageway 180e, the
block valve 162e is operably coupled to the side 176c of the flow
block 160a (adjacent the block valve 162a) and in fluid
communication with the internal region 178 thereof via the fluid
passageway 180f, and the block valve 162i is operably coupled to
the side 176c of the flow block 160a (adjacent the block valve
162e) and in fluid communication with the internal region 178
thereof via the fluid passageway 180g. The block valves 162c, 162g,
and 162k are operably coupled to the flow block 160b in
substantially the same manner as the manner in which the block
valves 162a, 162e, and 162i are operably coupled to the flow block
160a. The block valve 162m is operably coupled to the side 176b of
the flow block 160a and in fluid communication with the internal
region 178 thereof via the fluid passageway 180d. Moreover, the
block valve 162m is operably coupled to the flow block 160b in
substantially the same manner as the manner in which the block
valve 162m is operably coupled to the flow block 160a, except that
the block valve 162m is operably coupled to a side of the flow
block 160b analogous to the side 176a of the flow block 160a--as a
result, the block valve 162m is in fluid communication with an
internal region of the flow block 160b via a fluid passageway
analogous to the fluid passageway 180c of the flow block 160a.
[0110] In some embodiments, the operable coupling of the block
valves 162a, 162e, and 162i to the flow block 160a and the operable
coupling of the block valves 162c, 162g, and 162k to the flow block
160b reduces the number of fluid couplings, and thus potential leak
paths, required to make up the choke module 158. In some
embodiments, the manner in which the block valves 162a, 162e, and
162i are operably coupled to the flow block 160a and the manner in
which the block valves 162c, 162g, and 162k are operably coupled to
the flow block 160b permit the drilling chokes 166a-c to be
operably coupled in parallel between the flow blocks 160a and 160b.
In some embodiments, the spacing between the block valves 162a,
162e, and 162i operably coupled to the flow block 160a and the
spacing between the block valves 162c, 162g, and 162k operably
coupled to the flow block 160b permit the drilling chokes 166a-c to
be operably coupled in parallel between the flow blocks 160a and
160b.
[0111] When the MPD manifold 20 is assembled with the choke module
158, rather than the choke module 36, the valve module 40 is
operably coupled between the choke module 158 and the flow meter
module 38. More particularly, the valve 88a is operably coupled to
the end 174b of the flow block 160a and in fluid communication with
the internal region 178 thereof via the fluid passageway 180b, and
the valve 88c is operably coupled to the flow block 160b in
substantially the same manner as the manner in which the valve 88a
is operably coupled to the flow block 160a. In addition, the valve
88b is operably coupled to the spool 100a, opposite the flow block
98a, and the valve 88d is operably coupled to the flow meter 96,
opposite the flow block 98b. As a result, when the valve module 40
is operably coupled between the choke module 158 and the flow meter
module 38, as shown in FIGS. 10(a)-(f), the flow meter module 38
extends in a generally horizontal orientation. In those embodiments
in which the flow meter module 38 extends in the generally
horizontal orientation, the MPD manifold 20 is especially well
suited for use in onshore drilling operations. In some embodiments,
rather than the valve 88b being operably coupled to the spool 100a
and the valve 88d being operably coupled to the flow meter 96, the
valve 88b is operably coupled to the flow meter 96 and the valve
88d is operably coupled to the spool 100a.
[0112] In an embodiment, as illustrated in FIGS. 10(a)-(f), the MPD
manifold 20 further includes a flow fitting 182a operably coupled
to the side 90c of the flow block 86a and in fluid communication
with the internal region 92 thereof via the fluid passageway 94c,
and a flow fitting 182b operably coupled to the side 176a of the
flow block 160a and in fluid communication with the internal region
178 thereof via the fluid passageway 180c. Further, in addition to,
or instead of, the flow fitting 182b, the MPD manifold 20 may
include a flow fitting 184a operably coupled to the flow block 160b
in substantially the same manner as the manner in which the flow
fitting 182b is operably coupled to the flow block 160a, except
that the flow fitting 184a is operably coupled to a side of the
flow block 160b analogous to the side 176b of the flow block 160a.
Finally, in addition to, or instead of, the flow fitting 182a, the
MPD manifold 20 may include a flow fitting 184b operably coupled to
the flow block 86b in substantially the same manner as the manner
in which the flow fitting 182a is operably coupled to the flow
block 86a, except that the flow fitting 184b is operably coupled to
a side of the flow block 86b analogous to the side 90d of the flow
block 86a.
[0113] In those embodiments in which the MPD manifold 20 includes
the flow fittings 182a and 182b, the temperature sensor 48 and the
densometer 50 may be operably coupled to the valve module 40 (as
shown in FIG. 2) via the flow fitting 182a, and the temperature
sensor 44 and the densometer 46 may be operably coupled to the
choke module 158 (as shown in FIG. 2) via the flow fitting 182b. In
such embodiments, the flow fitting 182a is adapted to receive the
drilling mud from the RCD 16 and the MGS 22 is adapted to receive
the drilling mud from the flow fitting 182b. As a result, the
drilling mud may be permitted to flow through the flow meter 96
before flowing through the drilling chokes 166a, 166b, and/or 166c.
Additionally, in those embodiments in which the MPD manifold 20
includes the flow fittings 184a and 184b, the temperature sensor 48
and the densometer 50 may be operably coupled to the choke module
158 (as shown in FIG. 3) via the flow fitting 184a, and the
temperature sensor 44 and the densometer 46 may be operably coupled
to the valve module 40 (as shown in FIG. 3) via the flow fitting
184b. In such embodiments, the flow fitting 184a is adapted to
receive the drilling mud from the RCD 16 and the MGS 22 is adapted
to receive the drilling mud from the flow fitting 184b, as
described in further detail below with reference to FIG. 3. As a
result, the drilling mud may be permitted to flow through the
drilling chokes 166a, 166b, and/or 166c before flowing through the
flow meter 96.
[0114] In some embodiments, a measurement fitting 186 is operably
coupled to the flow block 160b and in fluid communication with an
internal region thereof via a fluid passageway analogous to the
fluid passageway 180a of the flow block 160a. In addition to, or
instead of, the measurement fitting 186, another measurement
fitting (not shown) may be operably coupled to the end 174a of the
flow block 160a and in fluid communication with the internal region
178 thereof via the fluid passageway 180a. In some embodiments,
pressure monitoring equipment 185 (shown in FIG. 10(a)) such as,
for example, electronic pressure monitoring equipment (including
one or more pressure sensors) for automatically controlling one or
more of the drilling chokes 166a, 166b, and/or 166c, is operably
coupled to the measurement fitting 186 and/or the measurement
fitting that is operably coupled to the flow block 160a. In
addition to, or instead of, the electronic pressure monitoring
equipment, the pressure monitoring equipment 185 may include analog
pressure monitoring equipment (including one or more pressure
sensors), which may be operably coupled to the measurement fitting
186 and/or the measurement fitting that is operably coupled to the
flow block 160a.
[0115] In an embodiment, as illustrated in FIGS. 12(a)-(d) with
continuing reference to FIGS. 10(a)-(f), the valve module 40 is
configurable so that, rather than the valve 88b being operably
coupled to the side 90b of the flow block 86a and in fluid
communication with the internal region 92 thereof via the fluid
passageway 94b, the valve 88b is operably coupled to the side 90e
of the flow block 86a and in fluid communication with the internal
region 92 thereof via the fluid passageway 94e. In addition, the
valve 88d is operably coupled to the flow block 86b in
substantially the same manner as the manner in which the valve 88b
is operably coupled to the flow block 86a. As a result, when the
valve module 40 is operably coupled between the choke module 158
and the flow meter module 38, as shown in FIGS. 12(a)-(d), the flow
meter module 38 extends in a generally vertical orientation, thus
significantly decreasing the overall footprint of the MPD manifold
20. In those embodiments in which the flow meter module 38 extends
in the generally vertical orientation, the MPD manifold 20 is
especially well suited for use in offshore drilling operations. In
some embodiments, the blind flange 95a is operably coupled to the
side 90b of the flow block 86a to prevent communication between the
internal region 92 and atmosphere. In some embodiments, the blind
flange 95b is operably coupled to the flow block 86b in
substantially the same manner as the manner in which the blind
flange 95a is operably coupled to the flow block 86a.
[0116] In some embodiments, to determine the weight of the drilling
mud: the temperature of the drilling mud measured by the
temperature sensor 44 is compared with the temperature of the
drilling mud measured by the temperature sensor 48; the density of
the drilling mud measured by the densometer 46 is compared with the
density of the drilling mud measured by the densometer 50; and/or
the respective pressure(s) of the drilling mud measured by the
pressure monitoring equipment 103 (shown in FIG. 10(f)) operably
coupled to the measurement fittings 102a and 102b, the pressure
monitoring equipment 185 (shown in FIG. 10(a)) operably coupled to
the measurement fitting 186, pressure monitoring equipment operably
coupled to another measurement fitting of the MPD manifold 20, or
any combination thereof, are compared. Thus, the temperature
sensors 44 and 48, the densometers 46 and 50, and/or the pressure
monitoring equipment 103 and/or 185 are operable to determine
whether the weight of the drilling mud is below a critical
threshold. In some embodiments, in response to a determination that
the weight of the drilling mud is below the critical threshold: the
weight of the drilling fluid circulated to the drilling tool (as
indicated by the arrows 30 and 32 in FIG. 1) is increased, and/or
the drilling chokes 166a, 166b, and/or 166c are adjusted to
increase the backpressure of the drilling mud within the wellbore
29. In this manner, the temperature sensors 44 and 48, the
densometers 46 and 50, and/or the pressure monitoring equipment 103
and/or 185 may be used to predict and prevent well kicks during
drilling operations.
[0117] In some embodiments, to determine the amount of gas
entrained in the drilling mud: the temperature of the drilling mud
measured by the temperature sensor 44 is compared with the
temperature of the drilling mud measured by the temperature sensor
48; the density of the drilling mud measured by the densometer 46
is compared with the density of the drilling mud measured by the
densometer 50; and/or the respective pressure(s) of the drilling
mud measured by the pressure monitoring equipment 103, the pressure
monitoring equipment 185, pressure monitoring equipment operably
coupled to another measurement fitting of the MPD manifold 20, or
any combination thereof, are compared. Thus, the temperature
sensors 44 and 48, the densometers 46 and 50, and/or the pressure
monitoring equipment 103 and/or 185 are operable to determine
whether the amount of gas entrained in the drilling mud is above a
critical threshold. In some embodiments, in response to a
determination that the amount of gas entrained in the drilling mud
is above the critical threshold: the weight of the drilling fluid
circulated to the drilling tool (as indicated by the arrows 30 and
32 in FIG. 1) is increased, and/or the drilling chokes 166a, 166b,
and/or 166c are adjusted to increase the backpressure of the
drilling mud within the wellbore 29. In this manner, the
temperature sensors 44 and 48, the densometers 46 and 50, and/or
the pressure monitoring equipment 103 and/or 185 may be used to
predict and prevent well kicks during drilling operations.
[0118] In some embodiments, the temperature and density of the
drilling mud measured before the drilling mud passes through the
drilling chokes 166a, 166b, and/or 166c are compared with the
temperature and density of the drilling mud after the drilling mud
passes through the drilling chokes 166a, 166b, and/or 166c.
Further, in some embodiments, the temperature and pressure of the
drilling mud measured before the drilling mud passes through the
drilling chokes 166a, 166b, and/or 166c are compared with the
temperature and pressure of the drilling mud measured after the
drilling mud passes through the drilling chokes 166a, 166b, and/or
166c. Further still, in some embodiments, the density and pressure
of the drilling mud measured before the drilling mud passes through
the drilling chokes 166a, 166b, and/or 166c are compared with the
density and pressure of the drilling mud measured after the
drilling mud passes through the drilling chokes 166a, 166b, and/or
166c. Finally, in some embodiments, the temperature, density, and
pressure of the drilling mud measured before the drilling mud
passes through the drilling chokes 166a, 166b, and/or 166c are
compared with the temperature, density, and pressure of the
drilling mud measured after the drilling mud passes through the
drilling chokes 166a, 166b, and/or 166c.
[0119] In an embodiment, as illustrated in FIG. 13, a method of
controlling backpressure of a drilling mud within a wellbore 29 is
diagrammatically illustrated and generally referred to by the
reference numeral 188. The method 188 includes receiving the
drilling mud from the wellbore 29 at a step 190; either:
controlling, using one or more of the drilling chokes 166a-c, the
backpressure of the drilling mud within the wellbore 29 at a step
192, the drilling chokes 166a-c being part of the choke module 158,
or bypassing the drilling chokes 166a-c of the choke module 158 at
a step 194; either: measuring, using the flow meter 96, a flow rate
of the drilling mud received from the wellbore 29 at a step 196,
the flow meter 96 being part of the flow meter module 38, or
bypassing the flow meter 96 of the flow meter module 38 at a step
198; and discharging the drilling mud at a step 200. In some
embodiments, the steps 196 and 198 of the method 188 are
substantially identical to the steps 134 and 136 of the method 124;
therefore, the steps 196 and 198 will not be discussed in further
detail.
[0120] The drilling mud is received from the wellbore 29 at the
step 190. In an embodiment of the step 190, the drilling mud is
received from the wellbore 29 via the flow fitting 182a operably
coupled to, and in fluid communication with, the internal region 92
of the flow block 86a via the fluid passageway 94c thereof. In
another embodiment of the step 190, the drilling mud is received
from the wellbore 29 via the flow fitting 184a operably coupled to
the flow block 160b in substantially the same manner as the manner
in which the flow fitting 182b is operably coupled to the flow
block 160a, except that the flow fitting 184a is operably coupled
to a side of the flow block 160b analogous to the side 176b of the
flow block 160a.
[0121] In some embodiments, one or more of the drilling chokes
166a-c control the backpressure of the drilling mud within the
wellbore 29 at the step 192. In an embodiment of the step 192, one
or more of the drilling chokes 166a-c are used to control the
backpressure of the drilling mud within the wellbore 29 by:
permitting fluid flow from the flow block 160b to the flow block
160a via one or both of the following element combinations: the
block valve 162c, the bleed valve 163b, the block valve 162d, the
drilling choke 166a, the block valve 162b, the bleed valve 163a,
and the block valve 162a; the block valve 162g, the bleed valve
163d, the block valve 162h, the drilling choke 166b, the block
valve 162f, the bleed valve 163c, and the block valve 162e; and the
block valve 162k, the bleed valve 163f, the block valve 162l, the
drilling choke 166c, the block valve 162j, the bleed valve 163e,
and the block valve 162i; and preventing, or at least reducing,
fluid flow from the flow block 160b to the flow block 160a via the
block valve 162e. More particularly, one or more of the drilling
chokes 166a-c may be used to control the backpressure of the
drilling mud within the wellbore 29 by actuating the block valves
162a-m so that: the block valves 162a-d are actuated to the open
configuration and the block valves 162e-m are actuated to the
closed configuration; the block valves 162e-h are actuated to the
open configuration and the block valves 162a-d and 162i-m are
actuated to the closed configuration; the block valves 162i-l are
actuated to the open configuration and the block valves 162a-h and
162m are actuated to the closed configuration; the block valves
162a-h are actuated to the open configuration and the block valves
162i-m are actuated to the closed configuration; the block valves
162a-d and 162i-l are actuated to the open configuration and the
block valves 162e-h and 162m are actuated to the closed
configuration; the block valves 162e-l are actuated to the open
configuration and the block valves 162a-d and 162m are actuated to
the closed configuration; or the block valves 162a-l are actuated
to the open configuration and the block valve 162m is actuated to
the closed configuration.
[0122] In some embodiments, the drilling chokes 166a-c are bypassed
at the step 194. In an embodiment of the step 194, the drilling
chokes 166a-c of the choke module 158 are bypassed by: permitting
fluid flow from the flow block 160b to the flow block 160a via the
block valve 162m; and preventing, or at least reducing, fluid flow
from the flow block 160b to the flow block 160a via each of the
following element combinations: the block valve 162c, the bleed
valve 163b, the block valve 162d, the drilling choke 166a, the
block valve 162b, the bleed valve 163a, and the block valve 162a;
the block valve 162g, the bleed valve 163d, the block valve 162h,
the drilling choke 166b, the block valve 162f, the bleed valve
163c, and the block valve 162e; and the block valve 162k, the bleed
valve 163f, the block valve 162l, the drilling choke 166c, the
block valve 162j, the bleed valve 163e, and the block valve 162i.
More particularly, the drilling chokes 166a-c of the choke module
158 are bypassed by actuating the block valves 162a-m so that: the
block valves 162a-l are closed and the block valve 162m is
open.
[0123] The method 188 includes discharging the drilling mud at the
step 200. In an embodiment of the step 200, the drilling mud is
discharged via either: the flow fitting 182b operably coupled to,
and in fluid communication with, the internal region 178 of the
flow block 160a via the fluid passageway 180c thereof; or the flow
fitting 184b operably coupled to the flow block 86b in
substantially the same manner as the manner in which the flow
fitting 182a is operably coupled to the flow block 86a, except that
the flow fitting 184b is operably coupled to a side of the flow
block 86b analogous to the side 90d of the flow block 86a.
[0124] In an embodiment of the steps 190 and 200, at the step 190
the drilling mud is received from the wellbore 29 via the flow
fitting 182a operably coupled to, and in fluid communication with,
the internal region 92 of the flow block 86a via the fluid
passageway 94c thereof, and at the step 200 the drilling mud is
discharged via the flow fitting 182b operably coupled to, and in
fluid communication with, the internal region 178 of the flow block
160a via the fluid passageway 180c thereof. In another embodiment
of the steps 190 and 200, at the step 190 the drilling mud is
received from the wellbore 29 via the flow fitting 184a operably
coupled to the flow block 160b in substantially the same manner as
the manner in which the flow fitting 182b is operably coupled to
the flow block 160a, and at the step 200 the drilling mud is
discharged via the flow fitting 184b operably coupled to the flow
block 86b in substantially the same manner as the manner in which
the flow fitting 182a is operably coupled to the flow block
86a.
[0125] In various embodiments, the steps of the method 188 may be
executed with different combinations of steps in different orders
and/or ways. For example, an embodiment of the method 188 includes:
the step 190 at which drilling mud is received from the wellbore 29
via the flow fitting 182a operably coupled to, and in fluid
communication with, the internal region 92 of the flow block 86a
via the fluid passageway 94c thereof; during and/or after the step
190, the step 196 at which the drilling mud flows from the flow
block 86a to the flow block 86b via the valve 88b, the spool 100a,
the flow block 98a, the spool 100b, the flow block 98b, the flow
meter 96, and the valve 88d (the valves 88a and 88e are closed);
during and/or after the step 196, the step 192 at which the
drilling mud flows from the flow block 86b to the flow block 160b
via the valve 88c, and from the flow block 160b to the flow block
160a via one or more of the following element combinations: the
block valve 162c, the bleed valve 163b, the block valve 162d, the
drilling choke 166a, the block valve 162b, the bleed valve 163a,
and the block valve 162a; the block valve 162g, the bleed valve
163d, the block valve 162h, the drilling choke 166b, the block
valve 162f, the bleed valve 163c, and the block valve 162e; and the
block valve 162k, the bleed valve 163f, the block valve 162l, the
drilling choke 166c, the block valve 162j, the bleed valve 163e,
and the block valve 162i (the block valve 162m is closed); and
during and/or after the step 192, the step 200 at which the
drilling mud is discharged via the flow fitting 182b operably
coupled to, and in fluid communication with, the internal region
178 of the flow block 160a via the fluid passageway 180c
thereof.
[0126] For another example, an embodiment of the method 188
includes: the step 190 at which drilling mud is received from the
wellbore 29 via the flow fitting 182a operably coupled to, and in
fluid communication with, the internal region 92 of the flow block
86a via the fluid passageway 94c thereof; during and/or after the
step 190, the step 198 at which the drilling mud flows from the
flow block 86a to the flow block 86b via the valve 88e (the valves
88a, 88b, and 88d are closed); during and/or after the step 198,
the step 192 at which the drilling mud flows from the flow block
86b to the flow block 160b via the valve 88c, and from the flow
block 160b to the flow block 160a via one or more of the following
element combinations: the block valve 162c, the bleed valve 163b,
the block valve 162d, the drilling choke 166a, the block valve
162b, the bleed valve 163a, and the block valve 162a; the block
valve 162g, the bleed valve 163d, the block valve 162h, the
drilling choke 166b, the block valve 162f, the bleed valve 163c,
and the block valve 162e; and the block valve 162k, the bleed valve
163f, the block valve 162l, the drilling choke 166c, the block
valve 162j, the bleed valve 163e, and the block valve 162i (the
block valve 162m is closed); and during and/or after the step 192,
the step 200 at which the drilling mud is discharged via the flow
fitting 182b operably coupled to, and in fluid communication with,
the internal region 178 of the flow block 160a via the fluid
passageway 180c thereof.
[0127] For yet another example, an embodiment of the method 188
includes: the step 190 at which drilling mud is received from the
wellbore 29 via the flow fitting 182a operably coupled to, and in
fluid communication with, the internal region 92 of the flow block
86a via the fluid passageway 94c thereof; during and/or after the
step 190, the step 196 at which the drilling mud flows from the
flow block 86a to the flow block 86b via the valve 88b, the spool
100a, the flow block 98a, the spool 100b, the flow block 98b, the
flow meter 96, and the valve 88d (the valves 88a and 88e are
closed); during and/or after the step 196, the step 194 at which
the drilling mud flows from the flow block 86b to the flow block
160b via the valve 88c, and from the flow block 160b to the flow
block 160a via the block valve 162m (the block valves 162a-l are
closed); and during and/or after the step 194, the step 200 at
which the drilling mud is discharged via the flow fitting 182b
operably coupled to, and in fluid communication with, the internal
region 178 of the flow block 160a via the fluid passageway 180c
thereof.
[0128] For yet another example, an embodiment of the method 188
includes: the step 190 at which drilling mud is received from the
wellbore 29 via the flow fitting 182a operably coupled to, and in
fluid communication with, the internal region 92 of the flow block
86a via the fluid passageway 94c thereof; during and/or after the
step 190, the step 198 at which the drilling mud flows from the
flow block 86a to the flow block 86b via the valve 88e (the valves
88a, 88b, and 88d are closed); during and/or after the step 198,
the step 194 at which the drilling mud flows from the flow block
86b to the flow block 160b via the valve 88c, and from the flow
block 160b to the flow block 160a via the block valve 162m (the
block valves 162a-l are closed); and during and/or after the step
194, the step 200 at which the drilling mud is discharged via the
flow fitting 182b operably coupled to, and in fluid communication
with, the internal region 178 of the flow block 160a via the fluid
passageway 180c thereof.
[0129] For yet another example, an embodiment of the method 188
includes: the step 190 at which the drilling mud is received from
the wellbore 29 via the flow fitting 184a operably coupled to the
flow block 160b in substantially the same manner as the manner in
which the flow fitting 182b is operably coupled to the flow block
160a; during and/or after the step 190, the step 192 at which the
drilling mud flows from the flow block 160b to the flow block 160a
via one or more of the following element combinations: the block
valve 162c, the bleed valve 163b, the block valve 162d, the
drilling choke 166a, the block valve 162b, the bleed valve 163a,
and the block valve 162a; the block valve 162g, the bleed valve
163d, the block valve 162h, the drilling choke 166b, the block
valve 162f, the bleed valve 163c, and the block valve 162e; and the
block valve 162k, the bleed valve 163f, the block valve 162l, the
drilling choke 166c, the block valve 162j, the bleed valve 163e,
and the block valve 162i (the block valve 162m is closed); during
and/or after the step 192, the step 196 at which the drilling mud
flows from the flow block 160a to the flow block 86a via the valve
88a, and from the flow block 86a to the flow block 86b via the
valve 88b, the spool 100a, the flow block 98a, the spool 100b, the
flow block 98b, the flow meter 96, and the valve 88d (the valves
88c and 88e are closed); and during and/or after the step 196, the
step 200 at which the drilling mud is discharged via the flow
fitting 184b operably coupled to the flow block 86b in
substantially the same manner as the manner in which the flow
fitting 182a is operably coupled to the flow block 86a.
[0130] For yet another example, an embodiment of the method 188
includes: the step 190 at which the drilling mud is received from
the wellbore 29 via the flow fitting 184a operably coupled to the
flow block 160b in substantially the same manner as the manner in
which the flow fitting 182b is operably coupled to the flow block
160a; during and/or after the step 190, the step 192 at which the
drilling mud flows from the flow block 160b to the flow block 160a
via one or more of the following element combinations: the block
valve 162c, the bleed valve 163b, the block valve 162d, the
drilling choke 166a, the block valve 162b, the bleed valve 163a,
and the block valve 162a; the block valve 162g, the bleed valve
163d, the block valve 162h, the drilling choke 166b, the block
valve 162f, the bleed valve 163c, and the block valve 162e; and the
block valve 162k, the bleed valve 163f, the block valve 162l, the
drilling choke 166c, the block valve 162j, the bleed valve 163e,
and the block valve 162i (the block valve 162m is closed); during
and/or after the step 192, the step 198 at which the drilling mud
flows from the flow block 160a to the flow block 86a via the valve
88a, and from the flow block 86a to the flow block 86b via the
valve 88e (the valves 88b, 88c and 88d are closed); and during
and/or after the step 198, the step 200 at which the drilling mud
is discharged via the flow fitting 184b operably coupled to the
flow block 86b in substantially the same manner as the manner in
which the flow fitting 182a is operably coupled to the flow block
86a.
[0131] For yet another example, an embodiment of the method 188
includes: the step 190 at which the drilling mud is received from
the wellbore 29 via the flow fitting 184a operably coupled to the
flow block 160b in substantially the same manner as the manner in
which the flow fitting 182b is operably coupled to the flow block
160a; during and/or after the step 190, the step 194 at which the
drilling mud flows from the flow block 160b to the flow block 160a
via the block valve 162m (the block valves 162a-1 are closed);
during and/or after the step 194, the step 196 at which the
drilling mud flows from the flow block 160a to the flow block 86a
via the valve 88a, and from the flow block 86a to the flow block
86b via the valve 88b, the spool 100a, the flow block 98a, the
spool 100b, the flow block 98b, the flow meter 96, and the valve
88d (the valves 88c and 88e are closed); and during and/or after
the step 196, the step 200 at which the drilling mud is discharged
via the flow fitting 184b operably coupled to the flow block 86b in
substantially the same manner as the manner in which the flow
fitting 182a is operably coupled to the flow block 86a.
[0132] Finally, for yet another example, an embodiment of the
method 188 includes: the step 190 at which the drilling mud is
received from the wellbore 29 via the flow fitting 184a operably
coupled to the flow block 160b in substantially the same manner as
the manner in which the flow fitting 182b is operably coupled to
the flow block 160a; during and/or after the step 190, the step 194
at which the drilling mud flows from the flow block 160b to the
flow block 160a via the block valve 162m (the block valves 162a-1
are closed); during and/or after the step 194, the step 198 at
which the drilling mud flows from the flow block 160a to the flow
block 86a via the valve 88a, and from the flow block 86a to the
flow block 86b via the valve 88e (the valves 88b-d are closed); and
during and/or after the step 198, the step 200 at which the
drilling mud is discharged via the flow fitting 184b operably
coupled to the flow block 86b in substantially the same manner as
the manner in which the flow fitting 182a is operably coupled to
the flow block 86a.
[0133] In some embodiments, the configuration of the MPD manifold
20, including the drilling chokes 166a-c and the flow meter 96 used
to carry out the method 188, optimizes the efficiency of the
drilling system 10, thereby improving the cost and effectiveness of
drilling operations. Such improved efficiency benefits operators
dealing with challenges such as, for example, continuous duty
operations, harsh downhole environments, and multiple
extended-reach lateral wells, among others. In some embodiments,
the configuration of the MPD manifold 20, including the drilling
chokes 166a-c and the flow meter 96 used to carry out the method
188, favorably affects the size and/or weight of the MPD manifold
20, and thus the transportability and overall footprint of the MPD
manifold 20 at the wellsite.
[0134] In some embodiments, the integrated nature of the drilling
chokes 166a-c and the flow meter 96 on the MPD manifold 20 used to
carry out the method 188 makes it easier to inspect, service, or
repair the MPD manifold 20, thereby decreasing downtime during
drilling operations. In some embodiments, the integrated nature of
the drilling chokes 166a-c and the flow meter 96 on the MPD
manifold 20 used to carry out the method 188 makes it easier to
coordinate the inspection, service, repair, or replacement of
components of the MPD manifold 20 such as, for example, the
drilling chokes 166a-c and/or the flow meter 96, among other
components. In this regard, an arrow 202 in FIGS. 10(b), 10(d),
12(b), and 12(c) indicates the direction in which the drilling
choke 166a is readily removable from the choke module 158 upon
decoupling of the spools 168a and 170a from the block valves 162b
and 162d, respectively, or decoupling of the flow block 164a and
the drilling choke 166a from the respective spools 168a and
170a.
[0135] Further, the arrow 202 indicates the direction in which the
drilling choke 166b is readily removable from the choke module 158
upon decoupling of the spools 168b and 170b from the block valves
162f and 162h, respectively, or decoupling of the flow block 164b
and the drilling choke 166b from the respective spools 168b and
170b. Further still, the arrow 202 indicates the direction in which
the drilling choke 166c is readily removable from the choke module
158 upon decoupling of the spools 168c and 170c from the block
valves 162j and 162l, respectively, or decoupling of the flow block
164c and the drilling choke 166c from the respective spools 168c
and 170c. Accordingly, one of the drilling chokes 166a-c may be
readily inspected, serviced, repaired, or replaced during drilling
operations while the other of the drilling chokes 166a-c remains in
service.
[0136] In an embodiment, as illustrated in FIG. 14, a method of
controlling backpressure of a drilling mud within a wellbore 29 is
diagrammatically illustrated and generally referred to by the
reference numeral 204. The method 204 includes receiving the
drilling mud from the wellbore 29 at a step 206; measuring, using a
first sensor, a first physical property of the drilling mud before
the drilling mud flows through the drilling chokes 166a, 166b,
and/or 166c at a step 208; flowing the drilling mud through the
drilling chokes 166a, 166b, and/or 166c at a step 210; measuring,
using a second sensor, the first physical property of the drilling
mud after the drilling mud flows through the drilling chokes 166a,
166b, and/or 166c at a step 212; comparing the respective
measurements of the first physical property taken by the first and
second sensors at a step 214; determining, based on at least the
comparison of the respective measurements of the first physical
property taken by the first and second sensors, an amount of gas
entrained in the drilling mud at a step 216; and adjusting the
drilling chokes 166a, 166b, and/or 166c, based on the determination
of the amount of gas entrained in the drilling mud, to control the
backpressure of the drilling mud within the wellbore 29 at a step
218. In some embodiments, when the amount of gas entrained in the
drilling mud is above a critical threshold, the drilling chokes
166a, 166b, and/or 166c are adjusted to increase the backpressure
of the drilling mud within the wellbore 29. In some embodiments, in
addition to, or instead of, determining the amount of gas entrained
in the drilling mud, the step 216 includes determining, based on at
least the comparison of the respective measurements of the first
physical property taken by the first and second sensors, the weight
of the drilling mud. As a result, the step 218 includes adjusting
the drilling chokes 166a, 166b, and/or 166c, based on the
determination of the weight of the drilling mud, to control the
backpressure of the drilling mud within the wellbore 29.
[0137] In an embodiment of the steps 208, 210, and 212, the first
physical property is density and the first and second sensors are
the densometers 46 and 50. In another embodiment of the steps 208,
210, and 212, the first physical property is temperature and the
first and second sensors are temperature sensors 44 and 48. In yet
another embodiment of the steps 208, 210, and 212, the first
physical property is pressure and the first and second sensors are
pressure sensors operably coupled to the measurement fittings 102a,
102b, 186, and/or another measurement fitting; in some embodiments,
these pressure sensors may be, may include, or may be a part of,
the pressure monitoring equipment 103 and/or 185.
[0138] In some embodiments of the method 204, the steps 208, 210,
and 212 further include measuring, using a third sensor, a second
physical property of the drilling mud before the drilling mud flows
through the drilling chokes 166a, 166b, and/or 166c, measuring,
using a fourth sensor, the second physical property of the drilling
mud after the drilling mud flows through the drilling chokes 166a,
166b, and/or 166c, and comparing the respective measurements of the
second physical property taken by the third and fourth sensors. In
some embodiments, determining the amount of gas entrained in the
drilling mud is further based on the comparison of the respective
measurements of the second physical property taken by the third and
fourth sensors. In an embodiment, the first physical property is
density and the first and second sensors are the densometers 46 and
50, and the second physical property is temperature and the third
and fourth sensors are the temperature sensors 44 and 48. In
another embodiment, the first physical property is density and the
first and second sensors are the densometers 46 and 50, and the
second physical property is pressure and the third and fourth
sensors are pressure sensors operably coupled to the measurement
fittings 102a, 102b, 186, and/or another measurement fitting; in
some embodiments, these pressure sensors may be, may include, or
may be a part of, the pressure monitoring equipment 103 and/or 185.
In yet another embodiment, the first physical property is
temperature and the first and second sensors are the temperature
sensors 44 and 48, and the second physical property is pressure and
the third and fourth sensors are pressure sensors operably coupled
to the measurement fittings 102a, 102b, 186, and/or another
measurement fitting.
[0139] In some embodiments of the method 204, the steps 208, 210,
and 212 further include measuring, using a fifth sensor, a third
physical property of the drilling mud before the drilling mud flows
through the drilling chokes 166a, 166b, and/or 166c, measuring,
using a sixth sensor, the third physical property of the drilling
mud after the drilling mud flows through the drilling chokes 166a,
166b, and/or 166c, and comparing the respective measurements of the
third physical property taken by the fifth and sixth sensors. In
some embodiments, determining the amount of gas entrained in the
drilling mud is further based on the comparison of the respective
measurements of the third physical property taken by the fifth and
sixth sensors. In an embodiment, the first physical property is
density and the first and second sensors are densometers 46 and 50,
the second physical property is temperature and the third and
fourth sensors are the temperature sensors 44 and 48, and the third
physical property is pressure and the fifth and sixth sensors are
pressure sensors operably coupled to the measurement fittings 102a,
102b, 186, and/or another measurement fitting; in some embodiments,
these pressure sensors may be, may include, or may be a part of,
the pressure monitoring equipment 103 and/or 185.
[0140] In some embodiments, during the operation of the MPD
manifold 20, the execution of the method 188, the execution of the
method 204, or any combination thereof, drilling mud is permitted
to flow through two of the drilling chokes 166a-c, and the two of
the drilling chokes 166a-c are controlled in accordance with the
foregoing; in some embodiments, the remaining one of the drilling
chokes 166a-c is closed but is nevertheless provided for redundancy
purposes such as, for example, in the event of operational problems
with one or both of the two of the drilling chokes 166a-c. In some
embodiments, during the operation of the MPD manifold 20, the
execution of the method 188, the execution of the method 204, or
any combination thereof, drilling mud is permitted to flow through
all three of the drilling chokes 166a-c, and all three of the
drilling chokes 166a-c are controlled in accordance with the
foregoing. In some embodiments, the above-described "double
block-and-bleed" functionality provided, in part, by the bleed
valves 163a-f, as well as the flow capacity provided by the use of
at least two of the drilling chokes 166a-c, make the choke module
158 especially suitable for offshore applications. In some
embodiments, the above-described "double block-and-bleed"
functionality provided, in part, by the bleed valves 163a-f, as
well as the flow capacity provided by the use of all of three of
the drilling chokes 166a-c, make the choke module 158 especially
suitable for offshore applications.
[0141] In an embodiment, as illustrated in FIG. 15, a control unit
is diagrammatically illustrated and generally referred to by the
reference numeral 220--the control unit 220 includes a processor
222 and a non-transitory computer readable medium 224 operably
coupled thereto, a plurality of instructions being stored on the
non-transitory computer readable medium 224, the instructions being
accessible to, and executable by, the processor 222. In some
embodiments, as illustrated in FIGS. 4(a)-(c), (e), and (f), the
control unit 220 is in communication with the drilling chokes 70a
and/or 70b. In those embodiments in which the choke module 36 is
omitted and replaced with the choke module 158, instead of being in
communication with the drilling chokes 70a and/or 70b, the control
unit 220 may be in communication with the drilling chokes 166a,
166b, and/or 166c, as illustrated in FIGS. 10(a)-(c), (e), and
(f).
[0142] In some embodiments, as illustrated in FIGS. 2 and 3, the
control unit 220 is also in communication with the flow meter
module 38 and, therefore, the control unit 220 may communicate
control signals to the drilling chokes 70a and/or 70b (or the
drilling chokes 166a, 166b, and/or 166c) based on measurement data
received from the flow meter module 38. In some embodiments, as
illustrated in FIGS. 2 and 3, the control unit 220 is also in
communication with the temperature sensors 44 and 48 and,
therefore, the control unit 220 may communicate control signals to
the drilling chokes 70a and/or 70b (or the drilling chokes 166a,
166b, and/or 166c) based on measurement data received from the
temperature sensors 44 and 48. In some embodiments, as illustrated
in FIGS. 2 and 3, the control unit 220 is also in communication
with the densometers 46 and 50 and, therefore, the control unit 220
may communicate control signals to the drilling chokes 70a and/or
70b (or the drilling chokes 166a, 166b, and/or 166c) based on
measurement data received from the densometers 46 and 50. In some
embodiments, the control unit 220 is also in communication with
pressure sensors operably coupled to the measurement fittings 102a,
102b, 108, 186 and/or another measurement fitting, and, therefore,
the control unit 220 may communicate control signals to the
drilling chokes 70a and/or 70b (or the drilling chokes 166a, 166b,
and/or 166c) based on measurement data received from the pressure
sensors; in some embodiments, these pressure sensors may be, may
include, or may be part of, the pressure monitoring equipment 103,
107, and/or 185. Finally, in some embodiments, the control unit 220
is also in communication with one or more other sensors associated
with the drilling system 10 such as, for example, one or more
sensors associated with the drilling tool 18, the wellhead 12, the
BOP 14, the RCD 16, the MGS 22, the flare 24, the shaker 26, and/or
the mud pump 28; therefore, the control unit 220 may communicate
control signals to the drilling chokes 70a and/or 70b (or the
drilling chokes 166a, 166b, and/or 166c) based on measurement data
received from the one or more sensors.
[0143] In some embodiments, a plurality of instructions, or
computer program(s), are stored on a non-transitory computer
readable medium, the instructions or computer program(s) being
accessible to, and executable by, one or more processors. In some
embodiments, the one or more processors execute the plurality of
instructions (or computer program(s)) to operate in whole or in
part the above-described embodiments. In some embodiments, the one
or more processors are part of the control unit 220, one or more
other computing devices, or any combination thereof. In some
embodiments, the non-transitory computer readable medium is part of
the control unit 220, one or more other computing devices, or any
combination thereof.
[0144] In an embodiment, as illustrated in FIG. 16, a computing
device 1000 for implementing one or more embodiments of one or more
of the above-described networks, elements, methods and/or steps,
and/or any combination thereof, is depicted. The computing device
1000 includes a microprocessor 1000a, an input device 1000b, a
storage device 1000c, a video controller 1000d, a system memory
1000e, a display 1000f, and a communication device 1000g all
interconnected by one or more buses 1000h. In some embodiments, the
storage device 1000c may include a floppy drive, hard drive,
CD-ROM, optical drive, any other form of storage device and/or any
combination thereof. In some embodiments, the storage device 1000c
may include, and/or be capable of receiving, a floppy disk, CD-ROM,
DVD-ROM, or any other form of computer-readable medium that may
contain executable instructions. In some embodiments, the
communication device 1000g may include a modem, network card, or
any other device to enable the computing device to communicate with
other computing devices. In some embodiments, any computing device
represents a plurality of interconnected (whether by intranet or
Internet) computer systems, including without limitation, personal
computers, mainframes, PDAs, smartphones and cell phones.
[0145] In some embodiments, one or more of the components of the
above-described embodiments include at least the computing device
1000 and/or components thereof, and/or one or more computing
devices that are substantially similar to the computing device 1000
and/or components thereof In some embodiments, one or more of the
above-described components of the computing device 1000 include
respective pluralities of same components.
[0146] In some embodiments, a computer system typically includes at
least hardware capable of executing machine readable instructions,
as well as the software for executing acts (typically
machine-readable instructions) that produce a desired result. In
some embodiments, a computer system may include hybrids of hardware
and software, as well as computer sub-systems.
[0147] In some embodiments, hardware generally includes at least
processor-capable platforms, such as client-machines (also known as
personal computers or servers), and hand-held processing devices
(such as smart phones, tablet computers, personal digital
assistants (PDAs), or personal computing devices (PCDs), for
example). In some embodiments, hardware may include any physical
device that is capable of storing machine-readable instructions,
such as memory or other data storage devices. In some embodiments,
other forms of hardware include hardware sub-systems, including
transfer devices such as modems, modem cards, ports, and port
cards, for example.
[0148] In some embodiments, software includes any machine code
stored in any memory medium, such as RAM or ROM, and machine code
stored on other devices (such as floppy disks, flash memory, or a
CD ROM, for example). In some embodiments, software may include
source or object code. In some embodiments, software encompasses
any set of instructions capable of being executed on a computing
device such as, for example, on a client machine or server.
[0149] In some embodiments, combinations of software and hardware
could also be used for providing enhanced functionality and
performance for certain embodiments of the present disclosure. In
an embodiment, software functions may be directly manufactured into
a silicon chip. Accordingly, it should be understood that
combinations of hardware and software are also included within the
definition of a computer system and are thus envisioned by the
present disclosure as possible equivalent structures and equivalent
methods.
[0150] In some embodiments, computer readable mediums include, for
example, passive data storage, such as a random access memory (RAM)
as well as semi-permanent data storage such as a compact disk read
only memory (CD-ROM). One or more embodiments of the present
disclosure may be embodied in the RAM of a computer to transform a
standard computer into a new specific computing machine. In some
embodiments, data structures are defined organizations of data that
may enable an embodiment of the present disclosure. In an
embodiment, a data structure may provide an organization of data,
or an organization of executable code.
[0151] In some embodiments, any networks and/or one or more
portions thereof, may be designed to work on any specific
architecture. In an embodiment, one or more portions of any
networks may be executed on a single computer, local area networks,
client-server networks, wide area networks, internets, hand-held
and other portable and wireless devices and networks.
[0152] In some embodiments, a database may be any standard or
proprietary database software. In some embodiments, the database
may have fields, records, data, and other database elements that
may be associated through database specific software. In some
embodiments, data may be mapped. In some embodiments, mapping is
the process of associating one data entry with another data entry.
In an embodiment, the data contained in the location of a character
file can be mapped to a field in a second table. In some
embodiments, the physical location of the database is not limiting,
and the database may be distributed. In an embodiment, the database
may exist remotely from the server, and run on a separate platform.
In an embodiment, the database may be accessible across the
Internet. In some embodiments, more than one database may be
implemented.
[0153] In some embodiments, a plurality of instructions stored on a
non-transitory computer readable medium may be executed by one or
more processors to cause the one or more processors to carry out or
implement in whole or in part the above-described operation of each
of the above-described embodiments of the drilling system 10, the
MPD manifold 20, the method 124, the method 142, the method 188,
the method 204, and/or any combination thereof. In some
embodiments, such a processor may include one or more of the
microprocessor 1000a, the processor 222, and/or any combination
thereof, and such a non-transitory computer readable medium may
include the computer readable medium 224 and/or may be distributed
among one or more components of the drilling system 10 and/or the
MPD manifold 20. In some embodiments, such a processor may execute
the plurality of instructions in connection with a virtual computer
system. In some embodiments, such a plurality of instructions may
communicate directly with the one or more processors, and/or may
interact with one or more operating systems, middleware, firmware,
other applications, and/or any combination thereof, to cause the
one or more processors to execute the instructions.
[0154] In a first aspect, the present disclosure introduces a
managed pressure drilling ("MPD") manifold adapted to receive
drilling mud from a wellbore, the MPD manifold including: a first
module including one or more drilling chokes; a second module
including a flow meter; and a third module including first and
second flow blocks operably coupled in parallel between the first
and second modules; wherein the one or more drilling chokes are
adapted to control backpressure of the drilling mud within the
wellbore; and wherein the flow meter is adapted to measure a flow
rate of the drilling mud received from the wellbore. In an
embodiment, the third module further includes: a first valve
operably coupled between, and in fluid communication with, the
first flow block and the first module; a second valve operably
coupled between, and in fluid communication with, the first flow
block and the second module; a third valve operably coupled
between, and in fluid communication with, the second flow block and
the first module; and a fourth valve operably coupled between, and
in fluid communication with, the second flow block and the second
module. In an embodiment, the third module further includes a fifth
valve operably coupled between, and in fluid communication with,
the first and second flow blocks. In an embodiment, the third
module is actuable between: a first configuration in which fluid
flow is permitted from the first flow block to the second flow
block via the second valve, the flow meter, and the fourth valve,
and fluid flow is prevented, or at least reduced, from the first
flow block to the second flow block via the fifth valve; and a
second configuration in which fluid flow is prevented, or at least
reduced, from the first flow block to the second flow block via the
second valve, the flow meter, and the fourth valve, and fluid flow
is permitted from the first flow block to the second flow block via
the fifth valve. In an embodiment, in the first configuration, the
first, second, third, fourth, and fifth valves are actuated so that
either: the second, third, and fourth valves are open and the first
and fifth valves are closed, or the first, second, and fourth
valves are open and the third and fifth valves are closed; and
wherein, in the second configuration, the first, second, third,
fourth, and fifth valves are actuated so that either: the third and
fifth valves are open and the first, second, and fourth valves are
closed, or the first and fifth valves are open and the second,
third, and fourth valves are closed. In an embodiment, the first
and second fluid passageways of the first flow block are generally
coaxial, and the first and second fluid passageways of the second
flow block are generally coaxial, so that the second module,
including the flow meter, extends in a generally horizontal
orientation. In an embodiment, the first and second fluid
passageways of the first flow block define generally perpendicular
axes, and the first and second fluid passageways of the second flow
block define generally perpendicular axes, so that the second
module, including the flow meter, extends in a generally vertical
orientation. In an embodiment, the first and second flow blocks
each include first, second, third, fourth, fifth, and sixth sides,
the third, fourth, fifth, and sixth sides extending between the
first and second sides, the first, third, and fourth fluid
passageways extending through the first, third, and fourth sides,
respectively, and the second fluid passageway extending through
either the second side or the fifth side. In an embodiment, the
second module further includes third and fourth flow blocks, and
first and second spools, the first spool being operably coupled to,
and in fluid communication with, the third flow block, the second
spool being operably coupled between, and in fluid communication
with, the third and fourth flow blocks, and the flow meter being
operably coupled to, and in fluid communication with, the fourth
flow block.
[0155] In a second aspect, the present disclosure also introduces a
managed pressure drilling ("MPD") manifold adapted to receive
drilling mud from a wellbore, the MPD manifold including: a first
module including one or more drilling chokes; a second module
including a flow meter; and a third module operably coupled
between, and in fluid communication with, the first and second
modules, the third module being configured to support the second
module in either: a generally horizontal orientation; or a
generally vertical orientation; wherein the one or more drilling
chokes are adapted to control backpressure of the drilling mud
within the wellbore; and wherein the flow meter is adapted to
measure a flow rate of the drilling mud received from the wellbore.
In an embodiment, the first and second modules are together mounted
to either a skid or a trailer so that, when so mounted, the first
and second modules are together towable between operational sites.
In an embodiment, the third module includes first and second flow
blocks operably coupled in parallel between the first and second
modules, the first and second flow blocks each defining an internal
region and first, second, third, fourth, and fifth fluid
passageways extending into the internal region. In an embodiment,
when the third module supports the second module in the generally
horizontal orientation: the first module is operably coupled to,
and in fluid communication with, the internal region of the first
flow block via the first fluid passageway thereof, and the second
module is operably coupled to, and in fluid communication with, the
internal region of the first flow block via the second fluid
passageway thereof; and the first module is operably coupled to,
and in fluid communication with, the internal region of the second
flow block via the first fluid passageway thereof, and the second
module is operably coupled to, and in fluid communication with, the
internal region of the second flow block via the second fluid
passageway thereof In an embodiment, when the third module supports
the second module in the generally vertical orientation: the first
module is operably coupled to, and in fluid communication with, the
internal region of the first flow block via the first fluid
passageway thereof, and the second module is operably coupled to,
and in fluid communication with, the internal region of the first
flow block via the fifth fluid passageway thereof; and the first
module is operably coupled to, and in fluid communication with, the
internal region of the second flow block via the first fluid
passageway thereof, and the second module is operably coupled to,
and in fluid communication with, the internal region of the second
flow block via the fifth fluid passageway thereof. In an
embodiment, the first and second flow blocks each include first,
second, third, fourth, fifth, and sixth sides, the third, fourth,
fifth, and sixth sides extending between the first and second
sides, and the first, second, third, fourth, and fifth fluid
passageways extending through the first, second, third, fourth, and
fifth sides. In an embodiment, the third module further includes
first, second, third, fourth, and fifth valves, the first and
second valves being operably coupled to, and in fluid communication
with, the first flow block and the respective first and second
modules, the third and fourth valves being operably coupled to, and
in fluid communication with, the second flow block and the
respective first and second modules, and the fifth valve being
operably coupled between, and in fluid communication with, the
first and second flow blocks. In an embodiment, the second module
further includes first and second flow blocks, and first and second
spools, the first spool being operably coupled to, and in fluid
communication with, the first flow block, the second spool being
operably coupled between, and in fluid communication with, the
first and second flow blocks, and the flow meter being operably
coupled to, and in fluid communication with, the second flow
block.
[0156] In a third aspect, the present disclosure also introduces a
managed pressure drilling ("MPD") manifold adapted to receive
drilling mud from a wellbore, the MPD manifold including: a first
flow block into which the drilling mud is adapted to flow from the
wellbore; a second flow block into which the drilling mud is
adapted to flow from the first flow block; a first valve operably
coupled to the first and second flow blocks; and a choke module
including a first drilling choke, the choke module being actuable
between: a backpressure control configuration in which: the first
drilling choke is in fluid communication with the first flow block
to control backpressure of the drilling mud within the wellbore;
the second flow block is in fluid communication with the first flow
block via the first drilling choke; and the second flow block is
not in fluid communication with the first flow block via the first
valve; and a choke bypass configuration in which: the first
drilling choke is not in fluid communication with the first flow
block; the second flow block is not in fluid communication with the
first flow block via the first drilling choke; and the second flow
block is in fluid communication with the first flow block via the
first valve. In an embodiment, the MPD manifold further includes a
valve module operably coupled to the choke module, the valve module
including a second valve; and a flow meter module operably coupled
to the valve module, the flow meter module including a flow meter;
wherein the valve module is actuable between: a flow metering
configuration in which: the second flow block is in fluid
communication with the first flow block via the flow meter; and the
second flow block is not in fluid communication with the first flow
block via the second valve; and a meter bypass configuration in
which: the second flow block is not in fluid communication with the
first flow block via the flow meter; and the second flow block is
in fluid communication with the first flow block via the second
valve. In an embodiment, the choke module further includes a second
drilling choke; and wherein the second flow block is adapted to be
in fluid communication with the first flow block via one or both of
the first drilling choke and the second drilling choke. In an
embodiment, the valve module includes either the first flow block
or the second flow block. In an embodiment, the choke module
includes the first flow block and the valve module includes the
second flow block. In an embodiment, the choke module includes the
second flow block and the valve module includes the first flow
block. In an embodiment, the flow meter is a Coriolis flow meter.
In an embodiment, the choke module includes the first valve. In an
embodiment, the choke module includes either the first flow block
or the second flow block. In an embodiment, the choke module
includes the first valve, the first flow block, and the second flow
block.
[0157] In a fourth aspect, the present disclosure introduces a
choke module adapted to receive drilling mud from a wellbore, the
choke module including first and second fluid blocks; and first and
second drilling chokes operably coupled in parallel between the
first and second fluid blocks; wherein each of the first and second
drilling chokes is adapted to control a backpressure of the
drilling mud within the wellbore. In an embodiment, the choke
module further includes first, second, third, and fourth valves,
the first and second valves being operably coupled to, and in fluid
communication with, the first fluid block, the third and fourth
valves being operably coupled to, and in fluid communication with,
the second fluid block, the first drilling choke being operably
coupled between, and in fluid communication with, the first and
third valves, and the second drilling choke being operably coupled
between, and in fluid communication with, the second and fourth
valves. In an embodiment, the choke module further includes a fifth
valve operably coupled between, and in fluid communication with,
the first and second fluid blocks. In an embodiment, the choke
module is actuable between a first configuration in which fluid
flow is permitted from the first fluid block to the second fluid
block via one or both of the following element combinations: the
first valve, the first drilling choke, and the third valve, and the
second valve, the second drilling choke, and the fourth valve; and
fluid flow is prevented, or at least reduced, from the first fluid
block to the second fluid block via the fifth valve; and a second
configuration in which fluid flow is permitted from the first fluid
block to the second fluid block via the fifth valve; and fluid flow
is prevented, or at least reduced, from the first fluid block to
the second fluid block via each of the following element
combinations: the first valve, the first drilling choke, and the
third valve, and the second valve, the second drilling choke, and
the fourth valve. In an embodiment, when the choke module is in the
first configuration, the first, second, third, fourth, and fifth
valves are actuated so that either: the first and third valves are
open and the second, fourth, and fifth valves are closed, the
second and fourth valves are open and the first, third, and fifth
valves are closed, or the first, second, third, and fourth valves
are open and the fifth valve is closed; and, when the choke module
is in the second configuration, the first, second, third, fourth,
and fifth valves are actuated so that the first, second, third, and
fourth valves are closed and the fifth valve is open. In an
embodiment, the first and second fluid blocks each define an
internal region and first, second, third, and fourth fluid
passageways extending into the internal region. In an embodiment,
the first, second, and fifth valves are in fluid communication with
the internal region of the first fluid block via the respective
first, second, and third fluid passageways thereof; and the third,
fourth, and fifth valves are in fluid communication with the
internal region of the second fluid block via the respective first,
second, and fourth fluid passageways thereof. In an embodiment, the
first and second fluid blocks each include first and second ends,
and first, second, third, and fourth sides extending between the
first and second ends, the first and second fluid passageways
extending through the first side, and the third and fourth fluid
passageways extending through the second and third sides,
respectively.
[0158] In a fifth aspect, the present disclosure introduces a
method of controlling backpressure of a drilling mud within a
wellbore, the method including receiving the drilling mud from the
wellbore; either: controlling, using first and/or second drilling
chokes, the backpressure of the drilling mud within the wellbore,
the first and second drilling chokes being part of a first module,
the first module further including first and second fluid blocks
between which the first and second drilling chokes are operably
coupled in parallel, or bypassing the first and second drilling
chokes of the first module; and discharging the drilling mud. In an
embodiment, the first module further includes first, second, third,
and fourth valves, the first and second valves being operably
coupled to, and in fluid communication with, the first fluid block,
the third and fourth valves being operably coupled to, and in fluid
communication with, the second fluid block, the first drilling
choke being operably coupled between, and in fluid communication
with, the first and third valves, and the second drilling choke
being operably coupled between, and in fluid communication with,
the second and fourth valves. In an embodiment, the first module
further includes a fifth valve operably coupled between, and in
fluid communication with, the first and second fluid blocks. In an
embodiment, controlling, using the first and/or second drilling
chokes, the backpressure of the drilling mud within the wellbore
includes permitting fluid flow from the first fluid block to the
second fluid block via one or both of the following element
combinations: the first valve, the first drilling choke, and the
third valve, and the second valve, the second drilling choke, and
the fourth valve; and preventing, or at least reducing, fluid flow
from the first fluid block to the second fluid block via the fifth
valve; and bypassing the first and second drilling chokes of the
first module includes permitting fluid flow from the first fluid
block to the second fluid block via the fifth valve; and
preventing, or at least reducing, fluid flow from the first fluid
block to the second fluid block via each of the following element
combinations: the first valve, the first drilling choke, and the
third valve, and the second valve, the second drilling choke, and
the fourth valve. In an embodiment, controlling, using the first
and/or second drilling chokes, the backpressure of the drilling mud
within the wellbore includes actuating the first, second, third,
fourth, and fifth valves so that: the first and third valves are
open and the second, fourth, and fifth valves are closed, the
second and fourth valves are open and the first, third, and fifth
valves are closed, or the first, second, third, and fourth valves
are open and the fifth valve is closed; and bypassing the first and
second drilling chokes of the first module includes actuating the
first, second, third, fourth, and fifth valves so that the first,
second, third, and fourth valves are closed and the fifth valve is
open. In an embodiment, the first and second fluid blocks each
define an internal region and first, second, third, and fourth
fluid passageways extending into the internal region. In an
embodiment, the first, second, and fifth valves are in fluid
communication with the internal region of the first fluid block via
the respective first, second, and third fluid passageways thereof;
and the third, fourth, and fifth valves are in fluid communication
with the internal region of the second fluid block via the
respective first, second, and fourth fluid passageways thereof. In
an embodiment, the first and second fluid blocks each include first
and second ends, and first, second, third, and fourth sides
extending between the first and second ends, the first and second
fluid passageways extending through the first side, and the third
and fourth fluid passageways extending through the second and third
sides, respectively.
[0159] In a sixth aspect, the present disclosure introduces a
managed pressure drilling ("MPD") manifold adapted to receive
drilling mud from a wellbore, the MPD manifold including a first
module including one or more drilling chokes; a second module
including a flow meter; and a third module operably coupled
between, and in fluid communication with, the first and second
modules, the third module being configured to support the second
module in either: a generally horizontal orientation, or a
generally vertical orientation; wherein, when the MPD manifold
receives the drilling mud from the wellbore: the one or more
drilling chokes are adapted to control backpressure of the drilling
mud within the wellbore, and the flow meter is adapted to measure a
flow rate of the drilling mud received from the wellbore. In an
embodiment, the first and second modules are together mounted to
either a skid or a trailer so that, when so mounted, the first and
second modules are together towable between operational sites. In
an embodiment, the third module includes first and second flow
blocks operably coupled in parallel between the first and second
modules, the first and second flow blocks each defining an internal
region and first, second, third, fourth, and fifth fluid
passageways extending into the internal region. In an embodiment,
when the third module supports the second module in the generally
horizontal orientation: the first module is operably coupled to,
and in fluid communication with, the internal region of the first
flow block via the first fluid passageway thereof, and the second
module is operably coupled to, and in fluid communication with, the
internal region of the first flow block via the second fluid
passageway thereof; and the first module is operably coupled to,
and in fluid communication with, the internal region of the second
flow block via the first fluid passageway thereof, and the second
module is operably coupled to, and in fluid communication with, the
internal region of the second flow block via the second fluid
passageway thereof. In an embodiment, when the third module
supports the second module in the generally vertical orientation:
the first module is operably coupled to, and in fluid communication
with, the internal region of the first flow block via the first
fluid passageway thereof, and the second module is operably coupled
to, and in fluid communication with, the internal region of the
first flow block via the fifth fluid passageway thereof; and the
first module is operably coupled to, and in fluid communication
with, the internal region of the second flow block via the first
fluid passageway thereof, and the second module is operably coupled
to, and in fluid communication with, the internal region of the
second flow block via the fifth fluid passageway thereof. In an
embodiment, the first and second flow blocks each include first,
second, third, fourth, fifth, and sixth sides, the third, fourth,
fifth, and sixth sides extending between the first and second
sides, and the first, second, third, fourth, and fifth fluid
passageways extending through the first, second, third, fourth, and
fifth sides. In an embodiment, the third module further includes
first, second, third, fourth, and fifth valves, the first and
second valves being operably coupled to, and in fluid communication
with, the first flow block and the respective first and second
modules, the third and fourth valves being operably coupled to, and
in fluid communication with, the second flow block and the
respective first and second modules, and the fifth valve being
operably coupled between, and in fluid communication with, the
first and second flow blocks. In an embodiment, the third module is
actuable between: a first configuration in which fluid flow is
permitted from the first flow block to the second flow block via
the second valve, the flow meter, and the fourth valve, and fluid
flow is prevented, or at least reduced, from the first flow block
to the second flow block via the fifth valve; and a second
configuration in which fluid flow is prevented, or at least
reduced, from the first flow block to the second flow block via the
second valve, the flow meter, and the fourth valve, and fluid flow
is permitted from the first flow block to the second flow block via
the fifth valve. In an embodiment, in the first configuration, the
first, second, third, fourth, and fifth valves are actuated so that
either: the second, third, and fourth valves are open and the first
and fifth valves are closed, or the first, second, and fourth
valves are open and the third and fifth valves are closed; and, in
the second configuration, the first, second, third, fourth, and
fifth valves are actuated so that either: the third and fifth
valves are open and the first, second, and fourth valves are
closed, or the first and fifth valves are open and the second,
third, and fourth valves are closed. In an embodiment, the second
module further includes first and second flow blocks, and first and
second spools, the first spool being operably coupled to, and in
fluid communication with, the first flow block, the second spool
being operably coupled between, and in fluid communication with,
the first and second flow blocks, and the flow meter being operably
coupled to, and in fluid communication with, the fourth flow block.
In an embodiment, the flow meter is a coriolis flow meter.
[0160] In a seventh aspect, the present disclosure introduces a
method of controlling backpressure of a drilling mud within a
wellbore, the method including receiving the drilling mud from the
wellbore; either: controlling, using one or more drilling chokes,
the backpressure of the drilling mud within the wellbore, the one
or more drilling chokes being part of a first module, or bypassing
the one or more drilling chokes of the first module; either:
measuring, using a flow meter, a flow rate of the drilling mud
received from the wellbore, the flow meter being part of a second
module, or bypassing the flow meter of the second module;
communicating the drilling mud between the first and second modules
using a third module, the third module being configured to support
the second module in either: a generally horizontal orientation, or
a generally vertical orientation; and discharging the drilling mud.
In an embodiment, the first and second modules are together mounted
to either a skid or a trailer so that, when so mounted, the first
and second modules are together towable between operational sites.
In an embodiment, the third module includes first and second flow
blocks operably coupled in parallel between the first and second
modules, the first and second flow blocks each defining an internal
region and first, second, third, fourth, and fifth fluid
passageways extending into the internal region. In an embodiment,
when the third module supports the second module in the generally
horizontal orientation: the first module is operably coupled to,
and in fluid communication with, the internal region of the first
flow block via the first fluid passageway thereof, and the second
module is operably coupled to, and in fluid communication with, the
internal region of the first flow block via the second fluid
passageway thereof; and the first module is operably coupled to,
and in fluid communication with, the internal region of the second
flow block via the first fluid passageway thereof, and the second
module is operably coupled to, and in fluid communication with, the
internal region of the second flow block via the second fluid
passageway thereof. In an embodiment, when the third module
supports the second module in the generally vertical orientation:
the first module is operably coupled to, and in fluid communication
with, the internal region of the first flow block via the first
fluid passageway thereof, and the second module is operably coupled
to, and in fluid communication with, the internal region of the
first flow block via the fifth fluid passageway thereof; and the
first module is operably coupled to, and in fluid communication
with, the internal region of the second flow block via the first
fluid passageway thereof, and the second module is operably coupled
to, and in fluid communication with, the internal region of the
second flow block via the fifth fluid passageway thereof. In an
embodiment, the first and second flow blocks each include first,
second, third, fourth, fifth, and sixth sides, the third, fourth,
fifth, and sixth sides extending between the first and second
sides, and the first, second, third, fourth, and fifth fluid
passageways extending through the first, second, third, fourth, and
fifth sides. In an embodiment, the third module further includes
first, second, third, fourth, and fifth valves, the first and
second valves being operably coupled to, and in fluid communication
with, the first flow block and the respective first and second
modules, the third and fourth valves being operably coupled to, and
in fluid communication with, the second flow block and the
respective first and second modules, and the fifth valve being
operably coupled between, and in fluid communication with, the
first and second flow blocks. In an embodiment, communicating the
drilling mud between the first and second modules using the third
module includes: permitting fluid flow from the first flow block to
the second flow block via the second valve, the flow meter, and the
fourth valve; and preventing, or at least reducing, fluid flow from
the first flow block to the second flow block via the fifth valve;
and bypassing the flow meter of the second module includes:
preventing, or at least reducing, fluid flow from the first flow
block to the second flow block via the second valve, the flow
meter, and the fourth valve; and permitting fluid flow from the
first flow block to the second flow block via the fifth valve. In
an embodiment, communicating the drilling mud between the first and
second modules using the third module includes actuating the first,
second, third, fourth, and fifth valves so that either: the second,
third, and fourth valves are open and the first and fifth valves
are closed; or the first, second, and fourth valves are open and
the third and fifth valves are closed; and bypassing the flow meter
of the second module includes actuating the first, second, third,
fourth, and fifth valves so that either: the third and fifth valves
are open and the first, second, and fourth valves are closed; or
the first and fifth valves are open and the second, third, and
fourth valves are closed. In an embodiment, the second module
further includes first and second flow blocks, and first and second
spools, the first spool being operably coupled to, and in fluid
communication with, the first flow block, the second spool being
operably coupled between, and in fluid communication with, the
first and second flow blocks, and the flow meter being operably
coupled to, and in fluid communication with, the fourth flow block.
In an embodiment, the flow meter is a coriolis flow meter.
[0161] In an eighth aspect, the present disclosure introduces a
choke module adapted to receive drilling mud from a wellbore, the
choke module including a first fluid block defining an internal
region and first and second fluid passageways extending into the
internal region, the first fluid block including first and second
ends, and first, second, third, and fourth sides extending between
the first and second ends, the first and second fluid passageways
extending through the first side. In an embodiment, the choke
module further includes first and second drilling chokes operably
coupled to, and in fluid communication with, the internal region of
the first fluid block via the respective first and second fluid
passageways thereof; wherein each of the first and second drilling
chokes is adapted to control a backpressure of the drilling mud
within the wellbore. In an embodiment, the choke module further
includes a first valve operably coupled between, and in fluid
communication with, the first fluid block and the first drilling
choke; and a second valve operably coupled between, and in fluid
communication with, the first fluid block and the second drilling
choke. In an embodiment, the choke module further includes a second
fluid block defining an internal region and first and second fluid
passageways extending into the internal region, the second fluid
block including first and second ends, and first, second, third,
and fourth sides extending between the first and second ends, the
first and second fluid passageways extending through the first
side; wherein the first and second drilling chokes are operably
coupled to, and in fluid communication with, the internal region of
the second fluid block via the respective first and second fluid
passageways thereof. In an embodiment, the choke module further
includes a valve operably coupled between, and in fluid
communication with, the respective internal regions of the first
and second fluid blocks. In an embodiment, the choke module further
includes a first valve operably coupled between, and in fluid
communication with, the second fluid block and the first drilling
choke; and a second valve operably coupled between, and in fluid
communication with, the second fluid block and the second drilling
choke. In an embodiment, the first fluid block further defines a
third fluid passageway extending through the second side thereof
and adapted to receive the drilling mud from the wellbore. In an
embodiment, the first fluid block further defines a fourth fluid
passageway extending through the first end thereof and adapted to
communicate the drilling mud via a measurement fitting connected to
the first end.
[0162] In a ninth aspect, the present disclosure introduces a
method of controlling backpressure of a drilling mud within a
wellbore, the method including receiving the drilling mud from the
wellbore; measuring, using a first sensor, a first physical
property of the drilling mud before the drilling mud flows through
one or more drilling chokes; flowing the drilling mud through the
one or more drilling chokes; measuring, using a second sensor, the
first physical property of the drilling mud after the drilling mud
flows through the one or more drilling chokes; comparing the
respective measurements of the first physical property taken by the
first and second sensors; determining, based on at least the
comparison of the respective measurements of the first physical
property taken by the first and second sensors, an amount of gas
entrained in the drilling mud; and adjusting the one or more
drilling chokes, based on at least the determination of the amount
of gas entrained in the drilling mud, to control the backpressure
of the drilling mud within the wellbore; wherein, when the amount
of gas entrained in the drilling mud is above a critical threshold,
the one or more drilling chokes are adjusted to increase the
backpressure of the drilling mud within the wellbore. In an
embodiment, the first physical property is density and the first
and second sensors are densometers. In an embodiment, the first
physical property is temperature and the first and second sensors
are temperature sensors. In an embodiment, the first physical
property is pressure and the first and second sensors are pressure
sensors. In an embodiment, the method further includes measuring,
using a third sensor, a second physical property of the drilling
mud before the drilling mud flows through the one or more drilling
chokes; measuring, using a fourth sensor, the second physical
property of the drilling mud after the drilling mud flows through
the one or more drilling chokes; and comparing the respective
measurements of the second physical property taken by the third and
fourth sensors; wherein determining the amount of gas entrained in
the drilling mud is further based on the comparison of the
respective measurements of the second physical property taken by
the third and fourth sensors. In an embodiment, the first physical
property is density and the first and second sensors are
densometers; and the second physical property is temperature and
the third and fourth sensors are temperature sensors. In an
embodiment, the first physical property is density and the first
and second sensors are densometers; and the second physical
property is pressure and the third and fourth sensors are pressure
sensors. In an embodiment, the first physical property is
temperature and the first and second sensors are temperature
sensors; and the second physical property is pressure and the third
and fourth sensors are pressure sensors. In an embodiment, the
method further includes: measuring, using a fifth sensor, a third
physical property of the drilling mud before the drilling mud flows
through the one or more drilling chokes; measuring, using a sixth
sensor, the third physical property of the drilling mud after the
drilling mud flows through the one or more drilling chokes; and
comparing the respective measurements of the third physical
property taken by the fifth and sixth sensors; wherein determining
the amount of gas entrained in the drilling mud is further based on
the comparison of the respective measurements of the third physical
property taken by the fifth and sixth sensors. In an embodiment,
the first physical property is density and the first and second
sensors are densometers; the second physical property is
temperature and the third and fourth sensors are temperature
sensors; and the third physical property is pressure and the fifth
and sixth sensors are pressure sensors.
[0163] In a tenth aspect, the present disclosure introduces a
managed pressure drilling ("MPD") manifold adapted to receive
drilling mud from a wellbore, the MPD manifold including a first
module including one or more drilling chokes; and a second module
including a flow meter, the second module being operably coupleable
to the first module in either: a generally horizontal orientation,
or a generally vertical orientation; wherein the first and second
modules are together mounted to either a skid or a trailer so that,
when so mounted, the first and second modules are together towable
between operational sites; and wherein, when the MPD manifold
receives the drilling mud from the wellbore: the one or more
drilling chokes are adapted to control backpressure of the drilling
mud within the wellbore; and the flow meter is adapted to measure a
flow rate of the drilling mud received from the wellbore. In an
embodiment, the first module further includes first and second
fluid blocks, the one or more drilling chokes of the first module
including first and second drilling chokes operably coupled in
parallel between the first and second fluid blocks. In an
embodiment, the first module further includes first, second, third,
and fourth valves, the first and second valves being operably
coupled to, and in fluid communication with, the first fluid block,
the third and fourth valves being operably coupled to, and in fluid
communication with, the second fluid block, the first drilling
choke being operably coupled between, and in fluid communication
with, the first and third valves, and the second drilling choke
being operably coupled between, and in fluid communication with,
the second and fourth valves. In an embodiment, the first module
further includes a fifth valve operably coupled between, and in
fluid communication with, the first and second fluid blocks. In an
embodiment, the first module is actuable between: a first
configuration in which: fluid flow is permitted from the second
fluid block to the first fluid block via one or both of the
following element combinations: the first valve, the first drilling
choke, and the third valve; and the second valve, the second
drilling choke, and the fourth valve; and fluid flow is prevented,
or at least reduced, from the second fluid block to the first fluid
block via the fifth valve; and a second configuration in which:
fluid flow is permitted from the second fluid block to the first
fluid block via the fifth valve; and fluid flow is prevented, or at
least reduced, from the second fluid block to the first fluid block
via each of the following element combinations: the first valve,
the first drilling choke, and the third valve; and the second
valve, the second drilling choke, and the fourth valve. In an
embodiment, in the first configuration, the first, second, third,
fourth, and fifth valves are actuated so that either: the first and
third valves are open and the second, fourth, and fifth valves are
closed, the second and fourth valves are open and the first, third,
and fifth valves are closed, or the first, second, third, and
fourth valves are open and the fifth valve is closed; and, in the
second configuration, the first, second, third, fourth, and fifth
valves are actuated so that: the first, second, third, and fourth
valves are closed and the fifth valve is open. In an embodiment,
the first and second fluid blocks each define an internal region
and first, second, third, fourth, fifth, and sixth fluid
passageways extending into the internal region. In an embodiment,
the first, second, and fifth valves are in fluid communication with
the internal region of the first fluid block via the respective
fifth, sixth, and fourth fluid passageways thereof; and the third,
fourth, and fifth valves are in fluid communication with the
internal region of the second fluid block via the respective fifth,
sixth, and third fluid passageways thereof. In an embodiment, the
MPD manifold further includes a third module operably coupled to,
and in fluid communication with: the internal region of the first
fluid block via the second fluid passageway thereof; the internal
region of the second fluid block via the second fluid passageway
thereof; and the flow meter of the second module. In an embodiment,
the first module further includes one or both of: a first flow
fitting operably coupled to, and in fluid communication with, the
internal region of the second fluid block via the fourth fluid
passageway thereof, the first flow fitting being adapted to receive
the drilling mud from the wellbore; and a second flow fitting
operably coupled to, and in fluid communication with, the internal
region of the first fluid block via the third fluid passageway
thereof, the second flow fitting being adapted to discharge the
drilling mud from the first module. In an embodiment, the first
module further includes one or both of: a first measurement fitting
operably coupled to, and in fluid communication with, the internal
region of the first fluid block via the first fluid passageway
thereof; and a second measurement fitting operably coupled to, and
in fluid communication with, the internal region of the second
fluid block via the first fluid passageway thereof. In an
embodiment, the first and second fluid blocks each include first
and second ends, and first, second, third, and fourth sides
extending between the first and second ends, the first and second
fluid passageways extending through the first and second ends,
respectively, the third and fourth fluid passageways extending
through the first and second sides, respectively, and the fifth and
sixth fluid passageways each extending through the third side. In
an embodiment, the second module further includes first and second
flow blocks, and first and second spools, the first spool being
operably coupled to, and in fluid communication with, the first
flow block, the second spool being operably coupled between, and in
fluid communication with, the first and second flow blocks, and the
flow meter being operably coupled to, and in fluid communication
with, the second flow block. In an embodiment, the second module
further includes one or both of: a first measurement fitting
operably coupled to, and in fluid communication with, the first
flow block; and a second measurement fitting operably coupled to,
and in fluid communication with, the second flow block. In an
embodiment, the flow meter is a coriolis flow meter. In an
embodiment, the MPD manifold further includes a third module, the
third module including first and second flow blocks and first,
second, third, and fourth valves, the first valve being operably
coupled to, and in fluid communication with, the first flow block
and the first module, the second valve being operably coupled to,
and in fluid communication with, the first flow block and the
second module, the third valve being operably coupled to, and in
fluid communication with, the second flow block and the first
module, and the fourth valve being operably coupled to, and in
fluid communication with, the second flow block and the second
module. In an embodiment, the third module further includes a fifth
valve operably coupled between, and in fluid communication with,
the first and second flow blocks; and wherein the third module is
actuable between: a first configuration in which fluid flow is
permitted from the first flow block to the second flow block via
the second valve, the flow meter, and the fourth valve, and fluid
flow is prevented, or at least reduced, from the first flow block
to the second flow block via the fifth valve; and a second
configuration in which fluid flow is prevented, or at least
reduced, from the first flow block to the second flow block via the
second valve, the flow meter, and the fourth valve, and fluid flow
is permitted from the first flow block to the second flow block via
the fifth valve. In an embodiment, in the first configuration, the
first, second, third, fourth, and fifth valves are actuated so that
either: the second, third, and fourth valves are open and the first
and fifth valves are closed, or the first, second, and fourth
valves are open and the third and fifth valves are closed; and, in
the second configuration, the first, second, third, fourth, and
fifth valves are actuated so that either: the third and fifth
valves are open and the first, second, and fourth valves are
closed, or the first and fifth valves are open and the second,
third, and fourth valves are closed. In an embodiment, the first
and second flow blocks each define an internal region, and first,
second, third, and fourth fluid passageways, each extending into
the internal region. In an embodiment, the first, second, and fifth
valves are in fluid communication with the internal region of the
first flow block via the respective first, second, and fourth fluid
passageways thereof; and the third, fourth, and fifth valves are in
fluid communication with the internal region of the second flow
block via the respective first, second, and third fluid passageways
thereof. In an embodiment, the first and second fluid passageways
of the first flow block are generally coaxial and the first and
second fluid passageways of the second flow block are generally
coaxial so that the second module, including the flow meter,
extends in the generally horizontal orientation. In an embodiment,
the first and second fluid passageways of the first flow block
define generally perpendicular axes and the first and second fluid
passageways of the second flow block define generally perpendicular
axes so that the second module, including the flow meter, extends
in the generally vertical orientation. In an embodiment, the first
and second flow blocks each include first, second, third, fourth,
fifth, and sixth sides, the third, fourth, fifth, and sixth sides
extending between the first and second sides, the first, third, and
fourth fluid passageways extending through the respective first,
third, and fourth sides, and the second fluid passageway extending
through either the second side or the fifth side. In an embodiment,
the third module further includes one or both of: a first flow
fitting operably coupled to, and in fluid communication with, the
internal region of the first flow block via the third fluid
passageway thereof, the first flow fitting being adapted to receive
the drilling mud from the wellbore; or a second flow fitting
operably coupled to, and in fluid communication with, the internal
region of the second flow block via the fourth fluid passageway
thereof, the second flow fitting being adapted to discharge the
drilling mud from the third module.
[0164] In an eleventh aspect, the present disclosure introduces a
managed pressure drilling ("MPD") manifold adapted to receive
drilling mud from a wellbore, the MPD manifold including a first
module including: first and second fluid blocks, and first and
second drilling chokes operably coupled in parallel between the
first and second fluid blocks; and a second module including a flow
meter; wherein, when the MPD manifold receives the drilling mud
from the wellbore: the one or more drilling chokes are adapted to
control backpressure of the drilling mud within the wellbore; and
the flow meter is adapted to measure a flow rate of the drilling
mud received from the wellbore. In an embodiment, the first module
further includes first, second, third, and fourth valves, the first
and second valves being operably coupled to, and in fluid
communication with, the first fluid block, the third and fourth
valves being operably coupled to, and in fluid communication with,
the second fluid block, the first drilling choke being operably
coupled between, and in fluid communication with, the first and
third valves, and the second drilling choke being operably coupled
between, and in fluid communication with, the second and fourth
valves. In an embodiment, the first module further includes a fifth
valve operably coupled between, and in fluid communication with,
the first and second fluid blocks. In an embodiment, the first
module is actuable between: a first configuration in which: fluid
flow is permitted from the second fluid block to the first fluid
block via one or both of the following element combinations: the
first valve, the first drilling choke, and the third valve; and the
second valve, the second drilling choke, and the fourth valve; and
fluid flow is prevented, or at least reduced, from the second fluid
block to the first fluid block via the fifth valve; and a second
configuration in which: fluid flow is permitted from the second
fluid block to the first fluid block via the fifth valve; and fluid
flow is prevented, or at least reduced, from the second fluid block
to the first fluid block via each of the following element
combinations: the first valve, the first drilling choke, and the
third valve; and the second valve, the second drilling choke, and
the fourth valve. In an embodiment, in the first configuration, the
first, second, third, fourth, and fifth valves are actuated so that
either: the first and third valves are open and the second, fourth,
and fifth valves are closed, the second and fourth valves are open
and the first, third, and fifth valves are closed, or the first,
second, third, and fourth valves are open and the fifth valve is
closed; and, in the second configuration, the first, second, third,
fourth, and fifth valves are actuated so that: the first, second,
third, and fourth valves are closed and the fifth valve is open. In
an embodiment, the first and second fluid blocks each define an
internal region and first, second, third, fourth, fifth, and sixth
fluid passageways extending into the internal region. In an
embodiment, the first, second, and fifth valves are in fluid
communication with the internal region of the first fluid block via
the respective fifth, sixth, and fourth fluid passageways thereof;
and the third, fourth, and fifth valves are in fluid communication
with the internal region of the second fluid block via the
respective fifth, sixth, and third fluid passageways thereof. In an
embodiment, the MPD manifold further includes a third module
operably coupled to, and in fluid communication with: the internal
region of the first fluid block via the second fluid passageway
thereof; the internal region of the second fluid block via the
second fluid passageway thereof; and the flow meter of the second
module. In an embodiment, the first module further includes one or
both of: a first flow fitting operably coupled to, and in fluid
communication with, the internal region of the second fluid block
via the fourth fluid passageway thereof, the first flow fitting
being adapted to receive the drilling mud from the wellbore; and a
second flow fitting operably coupled to, and in fluid communication
with, the internal region of the first fluid block via the third
fluid passageway thereof, the second flow fitting being adapted to
discharge the drilling mud from the first module. In an embodiment,
the first module further includes one or both of: a first
measurement fitting operably coupled to, and in fluid communication
with, the internal region of the first fluid block via the first
fluid passageway thereof; and a second measurement fitting operably
coupled to, and in fluid communication with, the internal region of
the second fluid block via the first fluid passageway thereof. In
an embodiment, the first and second fluid blocks each include first
and second ends, and first, second, third, and fourth sides
extending between the first and second ends, the first and second
fluid passageways extending through the first and second ends,
respectively, the third and fourth fluid passageways extending
through the first and second sides, respectively, and the fifth and
sixth fluid passageways each extending through the third side. In
an embodiment, the second module further includes first and second
flow blocks, and first and second spools, the first spool being
operably coupled to, and in fluid communication with, the first
flow block, the second spool being operably coupled between, and in
fluid communication with, the first and second flow blocks, and the
flow meter being operably coupled to, and in fluid communication
with, the second flow block. In an embodiment, the second module
further includes one or both of: a first measurement fitting
operably coupled to, and in fluid communication with, the first
flow block; and a second measurement fitting operably coupled to,
and in fluid communication with, the second flow block. In an
embodiment, the flow meter is a coriolis flow meter.
[0165] In a twelfth aspect, the present disclosure introduces a
managed pressure drilling ("MPD") manifold adapted to receive
drilling mud from a wellbore, the MPD manifold including a first
module including one or more drilling chokes; a second module
including a flow meter; and a third module including first and
second flow blocks operably coupled in parallel between the first
and second modules; wherein, when the MPD manifold receives the
drilling mud from the wellbore: the one or more drilling chokes are
adapted to control backpressure of the drilling mud within the
wellbore; and the flow meter is adapted to measure a flow rate of
the drilling mud received from the wellbore. In an embodiment, the
third module further includes first, second, third, and fourth
valves, the first and second valves being operably coupled to, and
in fluid communication with, the first flow block and the
respective first and second modules, and the third and fourth
valves being operably coupled to, and in fluid communication with,
the second flow block and the respective first and second modules.
In an embodiment, the third module further includes a fifth valve
operably coupled between, and in fluid communication with, the
first and second flow blocks; and wherein the third module is
actuable between: a first configuration in which fluid flow is
permitted from the first flow block to the second flow block via
the second valve, the flow meter, and the fourth valve, and fluid
flow is prevented, or at least reduced, from the first flow block
to the second flow block via the fifth valve; and a second
configuration in which fluid flow is prevented, or at least
reduced, from the first flow block to the second flow block via the
second valve, the flow meter, and the fourth valve, and fluid flow
is permitted from the first flow block to the second flow block via
the fifth valve. In an embodiment, in the first configuration, the
first, second, third, fourth, and fifth valves are actuated so that
either: the second, third, and fourth valves are open and the first
and fifth valves are closed, or the first, second, and fourth
valves are open and the third and fifth valves are closed; and
wherein, in the second configuration, the first, second, third,
fourth, and fifth valves are actuated so that either: the third and
fifth valves are open and the first, second, and fourth valves are
closed, or the first and fifth valves are open and the second,
third, and fourth valves are closed. In an embodiment, the first
and second flow blocks each define an internal region, and first,
second, third, and fourth fluid passageways, each extending into
the internal region. In an embodiment, the first, second, and fifth
valves are in fluid communication with the internal region of the
first flow block via the respective first, second, and fourth fluid
passageways thereof; and the third, fourth, and fifth valves are in
fluid communication with the internal region of the second flow
block via the respective first, second, and third fluid passageways
thereof. In an embodiment, the first and second fluid passageways
of the first flow block are generally coaxial and the first and
second fluid passageways of the second flow block are generally
coaxial so that the second module, including the flow meter,
extends in a generally horizontal orientation. In an embodiment,
the first and second fluid passageways of the first flow block
define generally perpendicular axes and the first and second fluid
passageways of the second flow block define generally perpendicular
axes so that the second module, including the flow meter, extends
in a generally vertical orientation. In an embodiment, the first
and second flow blocks each include first, second, third, fourth,
fifth, and sixth sides, the third, fourth, fifth, and sixth sides
extending between the first and second sides, the first, third, and
fourth fluid passageways extending through the first, third, and
fourth sides, respectively, and the second fluid passageway
extending through either the second side or the fifth side. In an
embodiment, the third module further includes one or both of: a
first flow fitting operably coupled to, and in fluid communication
with, the internal region of the first flow block via the third
fluid passageway thereof, the first flow fitting being adapted to
receive the drilling mud from the wellbore; and a second flow
fitting operably coupled to, and in fluid communication with, the
internal region of the second flow block via the fourth fluid
passageway thereof, the second flow fitting being adapted to
discharge the drilling mud from the third module. In an embodiment,
the second module further includes third and fourth flow blocks,
and first and second spools, the first spool being operably coupled
to, and in fluid communication with, the third flow block, the
second spool being operably coupled between, and in fluid
communication with, the third and fourth flow blocks, and the flow
meter being operably coupled to, and in fluid communication with,
the fourth flow block. In an embodiment, the second module further
includes one or both of: a first measurement fitting operably
coupled to, and in fluid communication with, the third flow block;
and a second measurement fitting operably coupled to, and in fluid
communication with, the fourth flow block. In an embodiment, the
flow meter is a coriolis flow meter.
[0166] In a thirteenth aspect, the present disclosure introduces a
method of controlling backpressure of a drilling mud within a
wellbore, the method including receiving the drilling mud from the
wellbore; either: controlling, using one or more drilling chokes,
the backpressure of the drilling mud within the wellbore, the one
or more drilling chokes being part of a first module, or bypassing
the one or more drilling chokes of the first module; either:
measuring, using a flow meter, a flow rate of the drilling mud
received from the wellbore, the flow meter being part of a second
module, or bypassing the flow meter of the second module; and
discharging the drilling mud; wherein the second module is operably
coupleable to the first module in either: a generally horizontal
orientation, or a generally vertical orientation; and wherein the
first and second modules are together mounted to either a skid or a
trailer so that, when so mounted, the first and second modules are
together towable between operational sites. In an embodiment, the
first module further includes first and second fluid blocks, the
one or more drilling chokes of the first module including first and
second drilling chokes operably coupled in parallel between the
first and second fluid blocks. In an embodiment, the first module
further includes first, second, third, and fourth valves, the first
and second valves being operably coupled to, and in fluid
communication with, the first fluid block, the third and fourth
valves being operably coupled to, and in fluid communication with,
the second fluid block, the first drilling choke being operably
coupled between, and in fluid communication with, the first and
third valves, and the second drilling choke being operably coupled
between, and in fluid communication with, the second and fourth
valves. In an embodiment, the first module further includes a fifth
valve operably coupled between, and in fluid communication with,
the first and second fluid blocks. In an embodiment, controlling,
using the one or more drilling chokes, the backpressure of the
drilling mud within the wellbore includes: permitting fluid flow
from the second fluid block to the first fluid block via one or
both of the following element combinations: the first valve, the
first drilling choke, and the third valve; and the second valve,
the second drilling choke, and the fourth valve; and preventing, or
at least reducing, fluid flow from the second fluid block to the
first fluid block via the fifth valve; and bypassing the one or
more drilling chokes of the first module includes: permitting fluid
flow from the second fluid block to the first fluid block via the
fifth valve; and preventing, or at least reducing, fluid flow from
the second fluid block to the first fluid block via each of the
following element combinations: the first valve, the first drilling
choke, and the third valve; and the second valve, the second
drilling choke, and the fourth valve. In an embodiment,
controlling, using the one or more drilling chokes, the
backpressure of the drilling mud within the wellbore includes
actuating the first, second, third, fourth, and fifth valves so
that either: the first and third valves are open and the second,
fourth, and fifth valves are closed, the second and fourth valves
are open and the first, third, and fifth valves are closed, or the
first, second, third, and fourth valves are open and the fifth
valve is closed; and bypassing the one or more drilling chokes of
the first module includes actuating the first, second, third,
fourth, and fifth valves so that: the first, second, third, and
fourth valves are closed and the fifth valve is open. In an
embodiment, the first and second fluid blocks each define an
internal region and first, second, third, fourth, fifth, and sixth
fluid passageways extending into the internal region. In an
embodiment, the first, second, and fifth valves are in fluid
communication with the internal region of the first fluid block via
the respective fifth, sixth, and fourth fluid passageways thereof;
and the third, fourth, and fifth valves are in fluid communication
with the internal region of the second fluid block via the
respective fifth, sixth, and third fluid passageways thereof. In an
embodiment, the method further includes communicating, using a
third module, the drilling mud to the second module, the third
module being operably coupled to, and in fluid communication with:
the internal region of the first fluid block via the second fluid
passageway thereof; the internal region of the second fluid block
via the second fluid passageway thereof; and the flow meter of the
second module. In an embodiment, receiving the drilling mud from
the wellbore includes receiving, via a first flow fitting, the
drilling mud from the wellbore, the first flow fitting being
operably coupled to, and in fluid communication with either: the
internal region of the second fluid block via the fourth fluid
passageway thereof, or the third module; and discharging the
drilling mud includes discharging, via a second flow fitting, the
drilling mud, the second flow fitting being operably coupled to,
and in fluid communication with, either: the third module, or the
internal region of the first fluid block via the third fluid
passageway thereof. In an embodiment, the first module further
includes one or both of: a first measurement fitting operably
coupled to, and in fluid communication with, the internal region of
the first fluid block via the first fluid passageway thereof; and a
second measurement fitting operably coupled to, and in fluid
communication with, the internal region of the second fluid block
via the first fluid passageway thereof. In an embodiment, the first
and second fluid blocks each include first and second ends, and
first, second, third, and fourth sides extending between the first
and second ends, the first and second fluid passageways extending
through the first and second ends, respectively, the third and
fourth fluid passageways extending through the first and second
sides, respectively, and the fifth and sixth fluid passageways each
extending through the third side. In an embodiment, the second
module further includes first and second flow blocks, and first and
second spools, the first spool being operably coupled to, and in
fluid communication with, the first flow block, the second spool
being operably coupled between, and in fluid communication with,
the first and second flow blocks, and the flow meter being operably
coupled to, and in fluid communication with, the second flow block.
In an embodiment, the second module further includes one or both
of: a first measurement fitting operably coupled to, and in fluid
communication with, the first flow block; and a second measurement
fitting operably coupled to, and in fluid communication with, the
second flow block. In an embodiment, the flow meter is a coriolis
flow meter. In an embodiment, the method further includes
communicating, using a third module, the drilling fluid to the
second module, the third module including first and second flow
blocks and first, second, third, and fourth valves, the first valve
being operably coupled to, and in fluid communication with, the
first flow block and the first module, the second valve being
operably coupled to, and in fluid communication with, the first
flow block and the second module, the third valve being operably
coupled to, and in fluid communication with, the second flow block
and the first module, and the fourth valve being operably coupled
to, and in fluid communication with, the second flow block and the
second module. In an embodiment, the third module further includes
a fifth valve operably coupled between, and in fluid communication
with, the first and second flow blocks. In an embodiment,
communicating, using the third module, the drilling fluid to the
second module includes: permitting fluid flow from the first flow
block to the second flow block via the second valve, the flow
meter, and the fourth valve; and preventing, or at least reducing,
fluid flow from the first flow block to the second flow block via
the fifth valve; and wherein bypassing the flow meter of the second
module includes: preventing, or at least reducing, fluid flow from
the first flow block to the second flow block via the second valve,
the flow meter, and the fourth valve; and permitting fluid flow
from the first flow block to the second flow block via the fifth
valve. In an embodiment, communicating, using the third module, the
drilling fluid to the second module includes actuating the first,
second, third, fourth, and fifth valves so that either: the second,
third, and fourth valves are open and the first and fifth valves
are closed, or the first, second, and fourth valves are open and
the third and fifth valves are closed; and bypassing the flow meter
of the second module includes actuating the first, second, third,
fourth, and fifth valves so that either: the third and fifth valves
are open and the first, second, and fourth valves are closed, or
the first and fifth valves are open and the second, third, and
fourth valves are closed. In an embodiment, the first and second
flow blocks each define an internal region, and first, second,
third, and fourth fluid passageways, each extending into the
internal region. In an embodiment, the first, second, and fifth
valves are in fluid communication with the internal region of the
first flow block via the respective first, second, and fourth fluid
passageways thereof; and the third, fourth, and fifth valves are in
fluid communication with the internal region of the second flow
block via the respective first, second, and third fluid passageways
thereof. In an embodiment, the first and second fluid passageways
of the first flow block are generally coaxial and the first and
second fluid passageways of the second flow block are generally
coaxial so that the second module, including the flow meter,
extends in the generally horizontal orientation. In an embodiment,
the first and second fluid passageways of the first flow block
define generally perpendicular axes and the first and second fluid
passageways of the second flow block define generally perpendicular
axes so that the second module, including the flow meter, extends
in the generally vertical orientation. In an embodiment, the first
and second flow blocks each include first, second, third, fourth,
fifth, and sixth sides, the third, fourth, fifth, and sixth sides
extending between the first and second sides, the first, third, and
fourth fluid passageways extending through the respective first,
third, and fourth sides, and the second fluid passageway extending
through either the second side or the fifth side. In an embodiment,
receiving the drilling mud from the wellbore includes receiving,
via a first flow fitting, the drilling mud from the wellbore, the
first flow fitting being operably coupled to, and in fluid
communication with either: the first module, or the internal region
of the first flow block via the third fluid passageway thereof; and
discharging the drilling mud includes discharging, via a second
flow fitting, the drilling mud, the second flow fitting being
operably coupled to, and in fluid communication with, either: the
internal region of the second flow block via the fourth fluid
passageway thereof, or the first module.
[0167] In a fourteenth aspect, the present disclosure introduces a
method of controlling backpressure of a drilling mud within a
wellbore, the method including receiving the drilling mud from the
wellbore; either: controlling, using one or more drilling chokes,
the backpressure of the drilling mud within the wellbore, the one
or more drilling chokes being part of a first module, or bypassing
the one or more drilling chokes of the first module; either:
measuring, using a flow meter, a flow rate of the drilling mud
received from the wellbore, the flow meter being part of a second
module, or bypassing the flow meter of the second module; and
discharging the drilling mud; wherein the first module further
includes first and second fluid blocks, the one or more drilling
chokes of the first module including first and second drilling
chokes operably coupled in parallel between the first and second
fluid blocks. In an embodiment, the first module further includes
first, second, third, and fourth valves, the first and second
valves being operably coupled to, and in fluid communication with,
the first fluid block, the third and fourth valves being operably
coupled to, and in fluid communication with, the second fluid
block, the first drilling choke being operably coupled between, and
in fluid communication with, the first and third valves, and the
second drilling choke being operably coupled between, and in fluid
communication with, the second and fourth valves. In an embodiment,
the first module further includes a fifth valve operably coupled
between, and in fluid communication with, the first and second
fluid blocks. In an embodiment, controlling, using the one or more
drilling chokes, the backpressure of the drilling mud within the
wellbore includes permitting fluid flow from the second fluid block
to the first fluid block via one or both of the following element
combinations: the first valve, the first drilling choke, and the
third valve; and the second valve, the second drilling choke, and
the fourth valve; and preventing, or at least reducing, fluid flow
from the second fluid block to the first fluid block via the fifth
valve; and bypassing the one or more drilling chokes of the first
module includes permitting fluid flow from the second fluid block
to the first fluid block via the fifth valve; and preventing, or at
least reducing, fluid flow from the second fluid block to the first
fluid block via each of the following element combinations: the
first valve, the first drilling choke, and the third valve; and the
second valve, the second drilling choke, and the fourth valve. In
an embodiment, controlling, using the one or more drilling chokes,
the backpressure of the drilling mud within the wellbore includes
actuating the first, second, third, fourth, and fifth valves so
that either: the first and third valves are open and the second,
fourth, and fifth valves are closed, the second and fourth valves
are open and the first, third, and fifth valves are closed, or the
first, second, third, and fourth valves are open and the fifth
valve is closed; and bypassing the one or more drilling chokes of
the first module includes actuating the first, second, third,
fourth, and fifth valves so that: the first, second, third, and
fourth valves are closed and the fifth valve is open. In an
embodiment, the first and second fluid blocks each define an
internal region and first, second, third, fourth, fifth, and sixth
fluid passageways extending into the internal region. In an
embodiment, the first, second, and fifth valves are in fluid
communication with the internal region of the first fluid block via
the respective fifth, sixth, and fourth fluid passageways thereof;
and the third, fourth, and fifth valves are in fluid communication
with the internal region of the second fluid block via the
respective fifth, sixth, and third fluid passageways thereof. In an
embodiment, the method further includes communicating, using a
third module, the drilling mud to the second module, the third
module being operably coupled to, and in fluid communication with:
the internal region of the first fluid block via the second fluid
passageway thereof; the internal region of the second fluid block
via the second fluid passageway thereof; and the flow meter of the
second module. In an embodiment, receiving the drilling mud from
the wellbore includes receiving, via a first flow fitting, the
drilling mud from the wellbore, the first flow fitting being
operably coupled to, and in fluid communication with either: the
internal region of the second fluid block via the fourth fluid
passageway thereof, or the third module; and discharging the
drilling mud includes discharging, via a second flow fitting, the
drilling mud, the second flow fitting being operably coupled to,
and in fluid communication with, either: the third module, or the
internal region of the first fluid block via the third fluid
passageway thereof. In an embodiment, the first module further
includes one or both of: a first measurement fitting operably
coupled to, and in fluid communication with, the internal region of
the first fluid block via the first fluid passageway thereof; and a
second measurement fitting operably coupled to, and in fluid
communication with, the internal region of the second fluid block
via the first fluid passageway thereof. In an embodiment, the first
and second fluid blocks each include first and second ends, and
first, second, third, and fourth sides extending between the first
and second ends, the first and second fluid passageways extending
through the first and second ends, respectively, the third and
fourth fluid passageways extending through the first and second
sides, respectively, and the fifth and sixth fluid passageways each
extending through the third side. In an embodiment, the second
module further includes first and second flow blocks, and first and
second spools, the first spool being operably coupled to, and in
fluid communication with, the first flow block, the second spool
being operably coupled between, and in fluid communication with,
the first and second flow blocks, and the flow meter being operably
coupled to, and in fluid communication with, the second flow block.
In an embodiment, the second module further includes one or both
of: a first measurement fitting operably coupled to, and in fluid
communication with, the first flow block; and a second measurement
fitting operably coupled to, and in fluid communication with, the
second flow block. In an embodiment, the flow meter is a coriolis
flow meter.
[0168] In a fifteenth aspect, the present disclosure introduces a
method of controlling backpressure of a drilling mud within a
wellbore, the method including receiving the drilling mud from the
wellbore; either: controlling, using one or more drilling chokes,
the backpressure of the drilling mud within the wellbore, the one
or more drilling chokes being part of a first module, or bypassing
the one or more drilling chokes of the first module; either:
measuring, using a flow meter, a flow rate of the drilling mud
received from the wellbore, the flow meter being part of a second
module, or bypassing the flow meter of the second module;
communicating, using a third module, the drilling fluid to the
second module, the third module including first and second flow
blocks operably coupled in parallel between the first and second
modules; and discharging the drilling mud. In an embodiment, the
third module further includes first, second, third, and fourth
valves, the first valve being operably coupled to, and in fluid
communication with, the first flow block and the first module, the
second valve being operably coupled to, and in fluid communication
with, the first flow block and the second module, the third valve
being operably coupled to, and in fluid communication with, the
second flow block and the first module, and the fourth valve being
operably coupled to, and in fluid communication with, the second
flow block and the second module. In an embodiment, the third
module further includes a fifth valve operably coupled between, and
in fluid communication with, the first and second flow blocks. In
an embodiment, communicating, using the third module, the drilling
fluid to the second module includes: permitting fluid flow from the
first flow block to the second flow block via the second valve, the
flow meter, and the fourth valve; and preventing, or at least
reducing, fluid flow from the first flow block to the second flow
block via the fifth valve; and bypassing the flow meter of the
second module includes: preventing, or at least reducing, fluid
flow from the first flow block to the second flow block via the
second valve, the flow meter, and the fourth valve; and permitting
fluid flow from the first flow block to the second flow block via
the fifth valve. In an embodiment, communicating, using the third
module, the drilling fluid to the second module includes actuating
the first, second, third, fourth, and fifth valves so that either:
the second, third, and fourth valves are open and the first and
fifth valves are closed, or the first, second, and fourth valves
are open and the third and fifth valves are closed; and bypassing
the flow meter of the second module includes actuating the first,
second, third, fourth, and fifth valves so that either: the third
and fifth valves are open and the first, second, and fourth valves
are closed, or the first and fifth valves are open and the second,
third, and fourth valves are closed. In an embodiment, the first
and second flow blocks each define an internal region, and first,
second, third, and fourth fluid passageways, each extending into
the internal region. In an embodiment, the first, second, and fifth
valves are in fluid communication with the internal region of the
first flow block via the respective first, second, and fourth fluid
passageways thereof; and the third, fourth, and fifth valves are in
fluid communication with the internal region of the second flow
block via the respective first, second, and third fluid passageways
thereof. In an embodiment, the first and second fluid passageways
of the first flow block are generally coaxial and the first and
second fluid passageways of the second flow block are generally
coaxial so that the second module, including the flow meter,
extends in a generally horizontal orientation. In an embodiment,
the first and second fluid passageways of the first flow block
define generally perpendicular axes and the first and second fluid
passageways of the second flow block define generally perpendicular
axes so that the second module, including the flow meter, extends
in a generally vertical orientation. In an embodiment, the first
and second flow blocks each include first, second, third, fourth,
fifth, and sixth sides, the third, fourth, fifth, and sixth sides
extending between the first and second sides, the first, third, and
fourth fluid passageways extending through the respective first,
third, and fourth sides, and the second fluid passageway extending
through either the second side or the fifth side. In an embodiment,
receiving the drilling mud from the wellbore includes receiving,
via a first flow fitting, the drilling mud from the wellbore, the
first flow fitting being operably coupled to, and in fluid
communication with either: the first module, or the internal region
of the first flow block via the third fluid passageway thereof; and
discharging the drilling mud includes discharging, via a second
flow fitting, the drilling mud, the second flow fitting being
operably coupled to, and in fluid communication with, either: the
internal region of the second flow block via the fourth fluid
passageway thereof, or the first module. In an embodiment, the
second module further includes first and second flow blocks, and
first and second spools, the first spool being operably coupled to,
and in fluid communication with, the first flow block, the second
spool being operably coupled between, and in fluid communication
with, the first and second flow blocks, and the flow meter being
operably coupled to, and in fluid communication with, the second
flow block. In an embodiment, the second module further includes
one or both of: a first measurement fitting operably coupled to,
and in fluid communication with, the first flow block; and a second
measurement fitting operably coupled to, and in fluid communication
with, the second flow block. In an embodiment, the flow meter is a
coriolis flow meter.
[0169] It is understood that variations may be made in the
foregoing without departing from the scope of the present
disclosure.
[0170] In some embodiments, the elements and teachings of the
various embodiments may be combined in whole or in part in some or
all of the embodiments. In addition, one or more of the elements
and teachings of the various embodiments may be omitted, at least
in part, and/or combined, at least in part, with one or more of the
other elements and teachings of the various embodiments.
[0171] In some embodiments, while different steps, processes, and
procedures are described as appearing as distinct acts, one or more
of the steps, one or more of the processes, and/or one or more of
the procedures may also be performed in different orders,
simultaneously and/or sequentially. In some embodiments, the steps,
processes and/or procedures may be merged into one or more steps,
processes and/or procedures.
[0172] In some embodiments, one or more of the operational steps in
each embodiment may be omitted. Moreover, in some instances, some
features of the present disclosure may be employed without a
corresponding use of the other features. Moreover, one or more of
the above-described embodiments and/or variations may be combined
in whole or in part with any one or more of the other
above-described embodiments and/or variations.
[0173] In the foregoing description of certain embodiments,
specific terminology has been resorted to for the sake of clarity.
However, the disclosure is not intended to be limited to the
specific terms so selected, and it is to be understood that each
specific term includes other technical equivalents which operate in
a similar manner to accomplish a similar technical purpose. Terms
such as "left" and right", "front" and "rear", "above" and "below"
and the like are used as words of convenience to provide reference
points and are not to be construed as limiting terms.
[0174] In this specification, the word "comprising" is to be
understood in its "open" sense, that is, in the sense of
"including", and thus not limited to its "closed" sense, that is
the sense of "consisting only of". A corresponding meaning is to be
attributed to the corresponding words "comprise", "comprised" and
"comprises" where they appear.
[0175] Although some embodiments have been described in detail
above, the embodiments described are illustrative only and are not
limiting, and those skilled in the art will readily appreciate that
many other modifications, changes and/or substitutions are possible
in the embodiments without materially departing from the novel
teachings and advantages of the present disclosure. Accordingly,
all such modifications, changes, and/or substitutions are intended
to be included within the scope of this disclosure as defined in
the following claims. In the claims, any means-plus-function
clauses are intended to cover the structures described herein as
performing the recited function and not only structural
equivalents, but also equivalent structures. Moreover, it is the
express intention of the applicant not to invoke 35 U.S.C. .sctn.
112, paragraph 6 for any limitations of any of the claims herein,
except for those in which the claim expressly uses the word "means"
together with an associated function.
* * * * *