U.S. patent application number 16/996085 was filed with the patent office on 2022-02-24 for surge control system for managed pressure drilling operations.
This patent application is currently assigned to Baker Hughes Oilfield Operations LLC. The applicant listed for this patent is Gregory Narro, Kyle O'Keefe, Mark Ramey. Invention is credited to Gregory Narro, Kyle O'Keefe, Mark Ramey.
Application Number | 20220056772 16/996085 |
Document ID | / |
Family ID | |
Filed Date | 2022-02-24 |
United States Patent
Application |
20220056772 |
Kind Code |
A1 |
O'Keefe; Kyle ; et
al. |
February 24, 2022 |
SURGE CONTROL SYSTEM FOR MANAGED PRESSURE DRILLING OPERATIONS
Abstract
A managed pressure drilling (MPD) system includes a work string
having one or more tubulars having an internal flow path. The work
string supports a liner string terminating in a liner float. A
liner hanger running tool is coupled to the work string uphole of
the liner string and the liner float. A selectively operable surge
control sub is arranged uphole of the liner hanger running tool,
and a selectively operable MPD sub is positioned uphole of the
liner hanger running tool and the selectively operable surge
control sub. The selectively operable MPD sub is operable to close
off the internal flow path to fluid pressure passing uphole from
the liner float in a first position during MPD operations and opens
the internal flow path to fluid pressure after the liner string
reaches a target depth.
Inventors: |
O'Keefe; Kyle; (Houston,
TX) ; Ramey; Mark; (Houston, TX) ; Narro;
Gregory; (Houston, TX) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
O'Keefe; Kyle
Ramey; Mark
Narro; Gregory |
Houston
Houston
Houston |
TX
TX
TX |
US
US
US |
|
|
Assignee: |
Baker Hughes Oilfield Operations
LLC
Houston
TX
|
Appl. No.: |
16/996085 |
Filed: |
August 18, 2020 |
International
Class: |
E21B 21/08 20060101
E21B021/08; E21B 21/10 20060101 E21B021/10; E21B 34/06 20060101
E21B034/06 |
Claims
1. A managed pressure drilling (MPD) system comprising: a work
string including one or more tubulars having an internal flow path,
the work string supporting a liner string terminating in a liner
float; a liner hanger running tool coupled to the work string
uphole of the liner string and the liner float; a selectively
operable surge control sub arranged uphole of the liner hanger
running tool; and a selectively operable MPD sub positioned uphole
of the liner hanger running tool and the selectively operable surge
control sub, the selectively operable MPD sub being operable to
close off the internal flow path to fluid pressure passing uphole
from the liner float in a first position during MPD operations and
opens the internal flow path to fluid pressure after the liner
string reaches a target depth.
2. The MPD system according to claim 1, wherein the selectively
operable MPD sub includes a housing having an uphole end, a
downhole end and a rotatable ball valve arranged between the uphole
end and the downhole end.
3. The MPD system according to claim 2, wherein the selectively
operable MPD sub includes an actuator member arranged between the
rotatable ball valve and the uphole end and a spring, the spring
urging the actuator member toward the rotatable ball valve.
4. The MPD system according to claim 3, further comprising: a shear
member selectively holding the actuator member in the first
position.
5. The MPD system according to claim 4, wherein the selectively
operable MPD sub includes a ball seat arranged between the
rotatable ball valve and the downhole end, the shear member
securing the ball seat to the housing.
6. The MPD system according to claim 2, wherein the selectively
operable MPD sub includes a tripping member arranged between the
rotatable ball valve and the downhole end.
7. The MPD system according to claim 6, wherein the rotatable ball
valve includes a recess receptive of the tripping member.
8. A resource exploration and recovery system comprising: a surface
system including a managed pressure drilling controller; a host
casing extending downhole into a wellbore; a subsurface system
including a work string extending through the host casing into the
wellbore, the work string including one or more tubulars having an
internal flow path, the work string including a liner string and a
liner float; a liner hanger running tool coupled to the work string
uphole of the liner string and the liner float; a selectively
operable surge control sub arranged uphole of the liner hanger
running tool; a selectively operable MPD sub positioned uphole of
the liner hanger running tool and the selectively operable surge
control sub, the selectively operable MPD sub being operable to
close off the internal flow path to fluid pressure passing uphole
from the liner float in a first position during MPD operations and
opens the internal flow path to fluid pressure after the liner
string reaches a target depth.
9. The MPD system according to claim 8, wherein the selectively
operable MPD sub includes a housing having an uphole end, a
downhole end and a rotatable ball valve arranged between the uphole
end and the downhole end.
10. The MPD system according to claim 9, wherein the selectively
operable MPD sub includes an actuator member arranged between the
rotatable ball valve and the uphole end and a spring, the spring
urging the actuator member toward the rotatable ball valve.
11. The MPD system according to claim 10, further comprising: a
shear member selectively holding the actuator member in the first
position.
12. The MPD system according to claim 11, wherein the selectively
operable MPD sub includes a ball seat arranged between the
rotatable ball valve and the downhole end, the shear member
securing the ball seat to the housing.
13. The MPD system according to claim 9, wherein the selectively
operable MPD sub includes a tripping member arranged between the
rotatable ball valve and the downhole end.
14. The MPD system according to claim 13, wherein the rotatable
ball valve includes a recess receptive of the tripping member.
15. A method of performing a managed pressure drilling (MPD)
operation comprising: performing surge reduction activities during
a managed pressure drilling (MPD) operations with an MPD system
supported on a work string including a liner hanger running tool, a
selectively operable surge control sub, and a selectively operable
MPD sub arranged uphole of a liner string; allowing fluid to freely
flow through the liner string into the liner hanger running tool;
dissipating surge pressure via the selectively operable surge
control sub positioned below the selectively operable MPD sub
without returning fluid up the work string; and opening the
selectively operable MPD sub and closing the selectively operable
surge control valve after the liner string has reached a target
depth.
16. The method of claim 15, wherein opening the selectively
operable MPD sub includes rotating a ball valve.
17. The method of claim 16, wherein rotating the ball valve
includes applying pressure to an actuator member to break a shear
member and release a spring.
18. The method of claim 17, wherein applying pressure to the
actuator member includes applying fluid pressure from a surface
system onto the rotating ball valve.
19. The method of claim 17, wherein applying pressure to the
actuator member includes forcing a ball seat arranged downhole of
the rotating ball valve against the hear member.
20. The method of claim 17, wherein rotating the ball valve
includes engaging the ball valve with a tripping member arranged in
the selectively operable MPD sub.
Description
BACKGROUND
[0001] In the resource recovery industry managed pressure drilling
is often used in order to reduce forces on a formation. During a
managed pressure drilling (MPD) operation, drillers manage wellbore
pressure constrained by formation property limits. Annular pressure
is maintained slightly above pore pressure to prevent an influx of
formation fluids into the wellbore and below fracture pressure by
using hydrostatic pressure created by the wellbore fluid combined
with added applied pressure down the annulus to create a downhole
combined pressure that exceeds pore pressure, but stays below
fracture gradient. The applied pressure down the annulus, if left
unchecked, will force fluid up the work string and onto the drill
floor/top drive/mud handling system.
[0002] Currently, fluid flow up the work string is controlled by
utilizing a drill-pipe float check valve during drilling operations
and casing float during casing operations. It is desirable to
control surge pressure during an MPD operation in order to prevent
fracturing/damaging the open formation in the well bore. With
conventional liner running operations, the use of a conventional
casing float places undesirable stresses on the formation due to a
large volume of fluid that is being displaced by the casing. In
addition, the passing drill pipe through the casing creates an
additional source of increased pressure.
[0003] Formation surface effects create stresses on the formation
that could lead to undesirable fracture gradient breakdown. While
running casing with an active MPD system, there is a need to reduce
formation surge effects while, at the same time, prevent mud from
being pushed up the drillstring. Accordingly, the industry would be
open to a system for reducing surge effects during an MPD
operation.
SUMMARY
[0004] Disclosed is a managed pressure drilling (MPD) system
including a work string having one or more tubulars having an
internal flow path. The work string supporting a liner string
terminating in a liner float. A liner hanger running tool is
coupled to the work string uphole of the liner string and the liner
float. A selectively operable surge control sub is arranged uphole
of the liner hanger running tool, and a selectively operable MPD
sub is positioned uphole of the liner hanger running tool and the
selectively operable surge control sub. The selectively operable
MPD sub is operable to close off the internal flow path to fluid
pressure passing uphole from the liner float in a first position
during MPD operations and opens the internal flow path to fluid
pressure after the liner string reaches a target depth.
[0005] Also disclosed is a resource exploration and recovery system
including a surface system having a managed pressure drilling
controller. A host casing extends downhole into a wellbore. A
subsurface system includes a work string extending from the surface
system through the host casing into the wellbore. The work string
includes one or more tubulars having an internal flow path, the
work string including a liner string and a liner float. A liner
hanger running tool is coupled to the work string uphole of the
liner string and the liner float. A selectively operable surge
control sub is arranged uphole of the liner hanger running tool. A
selectively operable MPD sub is positioned uphole of the liner
hanger running tool and the selectively operable surge control sub.
The selectively operable MPD sub is operable to close off the
internal flow path to fluid pressure passing uphole from the liner
float in a first position during MPD operations and opens the
internal flow path to fluid pressure after the liner string reaches
a target depth.
[0006] Further disclosed is a method of performing a managed
pressure drilling (MPD) operation including performing surge
reduction activities during a managed pressure drilling (MPD)
operations with an MPD system supported on a work string including
a liner hanger running tool, a selectively operable surge control
sub, and a selectively operable MPD sub arranged uphole of a liner
string, allowing fluid to freely flow through the liner string into
the liner hanger running tool, dissipating surge pressure via the
selectively operable surge control sub positioned below the
selectively operable MPD sub without returning fluid up the work
string, and opening the selectively operable MPD sub and closing
the selectively operable surge control valve after the liner string
has reached a target depth.
BRIEF DESCRIPTION OF THE DRAWINGS
[0007] The following descriptions should not be considered limiting
in any way. With reference to the accompanying drawings, like
elements are numbered alike:
[0008] FIG. 1 depicts a resource exploration and recovery system
having a managed pressure drilling (MPD) system, including an MPD
sub, a surge control valve, and a liner hanger running tool, in
accordance with an exemplary embodiment;
[0009] FIG. 2A depicts a first portion of a work string supporting
the MPD sub, surge control valve and liner hanger running tool, in
accordance with an exemplary aspect;
[0010] FIG. 2B depicts a second portion of the work string of FIG.
2A;
[0011] FIG. 2C depicts a third portion of the work string of FIG.
2A;
[0012] FIG. 3 depicts the MPD sub in a closed configuration for
lowering a liner to a target depth, in accordance with an exemplary
aspect; and
[0013] FIG. 4 depicts the MPD sub of FIG. 3 in an open
configuration for post MPD operations, in accordance with an
exemplary aspect.
DETAILED DESCRIPTION
[0014] A detailed description of one or more embodiments of the
disclosed apparatus and method are presented herein by way of
exemplification and not limitation with reference to the
Figures.
[0015] A resource exploration and recovery system, in accordance
with an exemplary embodiment, is indicated generally at 10, in FIG.
1. Resource exploration and recovery system 10 should be understood
to include well drilling operations, completions, resource
extraction and recovery, CO.sub.2 sequestration, and the like.
Resource exploration and recovery system 10 may include a first
system 14 which, in some environments, may take the form of a
surface system 16 operatively and fluidically connected to a second
system 18 which, in some environments, may take the form of a
subsurface or downhole system (not separately labeled).
[0016] First system 14 may include a control system 23 that may
provide power to, monitor, communicate with, and/or activate one or
more downhole operations as will be discussed herein. Surface
system 16 may include additional systems such as pumps, fluid
storage systems, cranes and the like (not shown).
[0017] Second system 18 includes a work string 30 that extends into
a wellbore 34 formed in a formation 36. Work string 30 may take the
form of a managed pressure drilling (MPD) string 38 formed from a
plurality of interconnected tubulars, one of which is indicated at
40. Wellbore 34 includes an annular wall 42 which may be defined by
a surface of formation 36. A host casing 48 extends from first
system 14 in a downhole direction. Work string 30 passes through
host casing 48 and, as will be detailed herein, supports a liner
string 50 that terminates in a liner float 52.
[0018] In an embodiment illustrated in FIGS. 2A-2C, work string 30
includes an internal flow path 54 that is fluidically connected to
a managed pressure drilling (MPD) system 58. Internal flow path 54
extends through work string 30 from a liner hanger running tool 62
that is operable to install liner string 50 inside wellbore 34.
Work string 30 also includes a selectively operable surge control
valve 64 and a selectively operable MPD sub 66 arranged uphole of
liner hanger running tool 62 within host casing 48. As will be
detailed more fully herein, a selectively operable surge control
valve 64 is positioned between selectively operable MPD sub 66 and
liner hanger running tool 62. Selectively operable MPD sub 66 is
operable to dissipate surge pressure during MPD operations. That
is, selectively operable MPD sub 66 substantially prevents fluid
pressure generated from MPD system 58 from passing uphole via
internal flow path 54 to surface system 16.
[0019] In an embodiment illustrated in FIGS. 3 and 4, selectively
operable MPD sub 66 includes a housing 78 having an outer surface
80 and an inner surface 82 that defines a valve chamber 85. A ball
seat 88 is supported in valve chamber 85. Ball seat 88 is coupled
to inner surface 82 through a shear member 90. A tripping member 92
is fixedly mounted relative to inner surface 82 radially outwardly
of ball seat 88. Ball seat 88 includes a curvilinear surface (not
separately labeled) that supports a rotatable ball valve 98.
Rotatable ball valve 98 includes a central passage 102 that may be
selectively aligned with internal flow path 54 and a recess 106
that is selectively receptive of tripping member 92.
[0020] Selectively operable MPD sub 66 is further shown to include
an activation member 110 arranged uphole of rotatable ball valve
98. Activation member 110 includes a ball engagement member 114
having a curvilinear surface (not separately labeled) that engages
rotatable ball valve 98. A conduit portion 117 extends axially
outwardly and upwardly from ball engagement member 114. A spring
119 extends about conduit portion 117. Spring 119 includes a first
end 121 that engages a surface (also not separately labeled) within
valve chamber 85 and a second end 123 that act upon ball engagement
member 114.
[0021] In operation, liner string 50 is run into wellbore 34 on
work string 30 with selectively operable MPD sub 66 in a closed
configuration such as shown in FIG. 3. MPD system 58 remains active
at surface to apply pressure via an external flow path (not
separately labeled) to wellbore 34 to maintain a selected operating
pressure. As liner string 50 progresses downhole, fluids are
displaced upwardly. Selectively operable MPD sub 66 ensures that
those fluids do not progress up internal flow path 54 beyond MPD
system 58 and interfere with well operations at surface system
12.
[0022] Once liner string 50 has reached target depth in wellbore
34, selectively operable MPD sub 66 may be opened and selectively
operable surge control valve 64 may be closed to circulate fluid
down internal flow path 54 and back up an annulus defined between
liner string 50 and annular wall 42 of wellbore 34 allowing
conventional activation of liner hanger running tool 62 and any
other tools below selectively operable MPD sub 66.
[0023] In an embodiment, pressure may be applied to rotatable ball
valve 98 via conduit portion 117. The pressure acts on ball seat 88
via rotatable ball valve 98 causing shear member 90 to give way.
Shear member 90 may break, shear, fracture or otherwise cease to be
an impediment to the movement of ball seat 88. That is, once shear
member 90 breaks, spring 119 acts on ball engagement member 114
forcing rotatable ball valve 98 downward. Recess 106 engages with
tripping member 92 causing rotatable ball valve 98 to rotate such
that central passage 102 aligns with internal flow path 54 thereby
fluidically connecting MPD system 58 with surface system 16.
[0024] Set forth below are some embodiments of the foregoing
disclosure:
[0025] Embodiment 1. A managed pressure drilling (MPD) system
comprising: a work string including one or more tubulars having an
internal flow path, the work string supporting a liner string
terminating in a liner float; a liner hanger running tool coupled
to the work string uphole of the liner string and the liner float;
a selectively operable surge control sub arranged uphole of the
liner hanger running tool; and a selectively operable MPD sub
positioned uphole of the liner hanger running tool and the
selectively operable surge control sub, the selectively operable
MPD sub being operable to close off the internal flow path to fluid
pressure passing uphole from the liner float in a first position
during MPD operations and opens the internal flow path to fluid
pressure after the liner string reaches a target depth.
[0026] Embodiment 2. The MPD system according to any prior
embodiment, wherein the selectively operable MPD sub includes a
housing having an uphole end, a downhole end and a rotatable ball
valve arranged between the uphole end and the downhole end.
[0027] Embodiment 3. The MPD system according to any prior
embodiment, wherein the selectively operable MPD sub includes an
actuator member arranged between the rotatable ball valve and the
uphole end and a spring, the spring urging the actuator member
toward the rotatable ball valve.
[0028] Embodiment 4. The MPD system according to any prior
embodiment, further comprising: a shear member selectively holding
the actuator member in the first position.
[0029] Embodiment 5. The MPD system according to any prior
embodiment, wherein the selectively operable MPD sub includes a
ball seat arranged between the rotatable ball valve and the
downhole end, the shear member securing the ball seat to the
housing.
[0030] Embodiment 6. The MPD system according to any prior
embodiment, wherein the selectively operable MPD sub includes a
tripping member arranged between the rotatable ball valve and the
downhole end.
[0031] Embodiment 7. The MPD system according to any prior
embodiment, wherein the rotatable ball valve includes a recess
receptive of the tripping member.
[0032] Embodiment 8. A resource exploration and recovery system
comprising: a surface system including a managed pressure drilling
controller; a host casing extending downhole into a wellbore; a
subsurface system including a work string extending through the
host casing into the wellbore, the work string including one or
more tubulars having an internal flow path, the work string
including a liner string and a liner float; a liner hanger running
tool coupled to the work string uphole of the liner string and the
liner float; a selectively operable surge control sub arranged
uphole of the liner hanger running tool; a selectively operable MPD
sub positioned uphole of the liner hanger running tool and the
selectively operable surge control sub, the selectively operable
MPD sub being operable to close off the internal flow path to fluid
pressure passing uphole from the liner float in a first position
during MPD operations and opens the internal flow path to fluid
pressure after the liner string reaches a target depth.
[0033] Embodiment 9. The MPD system according to any prior
embodiment, wherein the selectively operable MPD sub includes a
housing having an uphole end, a downhole end and a rotatable ball
valve arranged between the uphole end and the downhole end.
[0034] Embodiment 10. The MPD system according to any prior
embodiment, wherein the selectively operable MPD sub includes an
actuator member arranged between the rotatable ball valve and the
uphole end and a spring, the spring urging the actuator member
toward the rotatable ball valve.
[0035] Embodiment 11. The MPD system according to any prior
embodiment, further comprising: a shear member selectively holding
the actuator member in the first position.
[0036] Embodiment 12. The MPD system according to any prior
embodiment, wherein the selectively operable MPD sub includes a
ball seat arranged between the rotatable ball valve and the
downhole end, the shear member securing the ball seat to the
housing.
[0037] Embodiment 13. The MPD system according to any prior
embodiment, wherein the selectively operable MPD sub includes a
tripping member arranged between the rotatable ball valve and the
downhole end.
[0038] Embodiment 14. The MPD system according to any prior
embodiment, wherein the rotatable ball valve includes a recess
receptive of the tripping member.
[0039] Embodiment 15. A method of performing a managed pressure
drilling (MPD) operation comprising: performing surge reduction
activities during a managed pressure drilling (MPD) operations with
an MPD system supported on a work string including a liner hanger
running tool, a selectively operable surge control sub, and a
selectively operable MPD sub arranged uphole of a liner string;
allowing fluid to freely flow through the liner string into the
liner hanger running tool; dissipating surge pressure via the
selectively operable surge control sub positioned below the
selectively operable MPD sub without returning fluid up the work
string; and opening the selectively operable MPD sub and closing
the selectively operable surge control valve after the liner string
has reached a target depth.
[0040] Embodiment 16. The method according to any prior embodiment,
wherein opening the selectively operable MPD sub includes rotating
a ball valve.
[0041] Embodiment 17. The method according to any prior embodiment,
wherein rotating the ball valve includes applying pressure to an
actuator member to break a shear member and release a spring.
[0042] Embodiment 18. The method according to any prior embodiment,
wherein applying pressure to the actuator member includes applying
fluid pressure from a surface system onto the rotating ball
valve.
[0043] Embodiment 19. The method according to any prior embodiment,
wherein applying pressure to the actuator member includes forcing a
ball seat arranged downhole of the rotating ball valve against the
hear member.
[0044] Embodiment 20. The method according to any prior embodiment,
wherein rotating the ball valve includes engaging the ball valve
with a tripping member arranged in the selectively operable MPD
sub.
[0045] The use of the terms "a" and "an" and "the" and similar
referents in the context of describing the invention (especially in
the context of the following claims) are to be construed to cover
both the singular and the plural, unless otherwise indicated herein
or clearly contradicted by context. Further, it should be noted
that the terms "first," "second," and the like herein do not denote
any order, quantity, or importance, but rather are used to
distinguish one element from another.
[0046] The terms "about" and "substantially" are intended to
include the degree of error associated with measurement of the
particular quantity based upon the equipment available at the time
of filing the application. For example, "about" and/or
"substantially" can include a range of .+-.8% or 5%, or 2% of a
given value.
[0047] The teachings of the present disclosure may be used in a
variety of well operations. These operations may involve using one
or more treatment agents to treat a formation, the fluids resident
in a formation, a wellbore, and/or equipment in the wellbore, such
as production tubing. The treatment agents may be in the form of
liquids, gases, solids, semi-solids, and mixtures thereof.
Illustrative treatment agents include, but are not limited to,
fracturing fluids, acids, steam, water, brine, anti-corrosion
agents, cement, permeability modifiers, drilling muds, emulsifiers,
demulsifiers, tracers, flow improvers etc. Illustrative well
operations include, but are not limited to, hydraulic fracturing,
stimulation, tracer injection, cleaning, acidizing, steam
injection, water flooding, cementing, etc.
[0048] While the invention has been described with reference to an
exemplary embodiment or embodiments, it will be understood by those
skilled in the art that various changes may be made and equivalents
may be substituted for elements thereof without departing from the
scope of the invention. In addition, many modifications may be made
to adapt a particular situation or material to the teachings of the
invention without departing from the essential scope thereof.
Therefore, it is intended that the invention not be limited to the
particular embodiment disclosed as the best mode contemplated for
carrying out this invention, but that the invention will include
all embodiments falling within the scope of the claims. Also, in
the drawings and the description, there have been disclosed
exemplary embodiments of the invention and, although specific terms
may have been employed, they are unless otherwise stated used in a
generic and descriptive sense only and not for purposes of
limitation, the scope of the invention therefore not being so
limited.
* * * * *