U.S. patent application number 15/428792 was filed with the patent office on 2018-06-28 for downhole fluid-pressure safety bypass apparatus.
The applicant listed for this patent is Christopher Gasser, Brady Guilbeaux, Richard Messa, Ashley Rochon. Invention is credited to Christopher Gasser, Brady Guilbeaux, Richard Messa, Ashley Rochon.
Application Number | 20180179855 15/428792 |
Document ID | / |
Family ID | 62625666 |
Filed Date | 2018-06-28 |
United States Patent
Application |
20180179855 |
Kind Code |
A1 |
Messa; Richard ; et
al. |
June 28, 2018 |
DOWNHOLE FLUID-PRESSURE SAFETY BYPASS APPARATUS
Abstract
A downhole fluid-pressure safety bypass for coiled-tubing
operations, which diverts excessively pressurized drilling fluid
directly into the annulus, protecting the fluid motor and similar
downhole equipment from damage or reduced function, while allowing
greater fluid pressures to be used up-hole for purposes such as
increasing the flushing of cuttings up the annulus.
Inventors: |
Messa; Richard; (Broussard,
LA) ; Gasser; Christopher; (Houston, TX) ;
Guilbeaux; Brady; (Maurice, LA) ; Rochon; Ashley;
(New Iberia, LA) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
Messa; Richard
Gasser; Christopher
Guilbeaux; Brady
Rochon; Ashley |
Broussard
Houston
Maurice
New Iberia |
LA
TX
LA
LA |
US
US
US
US |
|
|
Family ID: |
62625666 |
Appl. No.: |
15/428792 |
Filed: |
February 9, 2017 |
Related U.S. Patent Documents
|
|
|
|
|
|
Application
Number |
Filing Date |
Patent Number |
|
|
15392846 |
Dec 28, 2016 |
|
|
|
15428792 |
|
|
|
|
Current U.S.
Class: |
1/1 |
Current CPC
Class: |
E21B 2200/06 20200501;
E21B 34/10 20130101; E21B 21/103 20130101 |
International
Class: |
E21B 34/10 20060101
E21B034/10; E21B 34/12 20060101 E21B034/12; E21B 21/10 20060101
E21B021/10 |
Claims
1. A downhole fluid-pressure safety bypass apparatus for
coiled-tubing operations having an annulus and having an up-hole
and downhole orientation, on a workstring having a central axial
conduit for drilling fluid of a standard cross-sectional area, and
a desired maximum pressure of drilling fluid in the downhole side
of the workstring, the downhole fluid-pressure safety bypass
comprising: (i) an intake tube section adapted to mount at an
up-hole end to a coiled-tubing workstring, having at an up-hole end
extending to the middle portion of said intake tube section a
central axial conduit for drilling fluid of a first cross-sectional
area smaller than standard, and having an enlargement of
cross-sectional area at a downhole end, defining a shoulder; (ii)
an outflow tube section adapted to mount at an up-hole end to the
downhole end of said intake tube section, and mount at a downhole
end to the downhole continuation of the coiled-tubing workstring,
having a central axial conduit for drilling fluid of size close to
the first cross-sectional area of said intake tube section, and
having an enlargement of cross-sectional area at a downhole end;
(iii) at least one fluid bypass port adapted to allow passage of
drilling fluid from the middle portion of the central axial conduit
of said intake tube section to the annulus; (iv) a calibrated
coiled spring adapted to fit into the enlarged-cross-sectional area
of said intake tube section such that said calibrated coiled spring
does not bind and does not block the flow of drilling fluid; and
(v) a flow-through sliding inner tube having an external size
matching the first cross-sectional area of said intake tube section
at an up-hole end, and having an increased external size larger
than the first cross-sectional area of said intake tube section,
defining a shoulder, at a downhole end, and having a central axial
conduit for drilling fluid, adapted to slide inside said intake
tube section and to block said fluid bypass ports when at an
up-hole position and to not block said fluid bypass ports when at a
downhole position; where, in use, at fluid pressures up to the
desired maximum, said flow-through sliding inner tube is pressed by
said calibrated coiled spring into an up-hole position such that
the shoulder of said flow-through sliding inner tube is stopped by
contact with the shoulder of said intake tube section and said
flow-through sliding inner tube blocks said fluid bypass ports, and
all of the fluid flows through said flow-through sliding inner tube
into said outflow tube section and into the downhole continuation
of the coiled-tubing workstring; where, in use, at fluid pressures
above the desired maximum, said flow-through sliding inner tube is
pressed to overcome said calibrated coiled spring and to slide into
a downhole position such that said flow-through sliding inner tube
does not block said fluid bypass ports, and a portion of the fluid
flows through said fluid bypass ports into the annulus; and where,
in use, said downhole fluid-pressure safety bypass prevents
excessively pressurized drilling fluid from flowing into the
downhole continuation of the coiled-tubing workstring by diverting
a portion of drilling fluid through said fluid bypass ports
directly into the annulus, thereby increasing flow up the
annulus.
2. The downhole downhole fluid-pressure safety bypass apparatus of
claim 1, further comprising being made of steel.
3. The downhole fluid-pressure safety bypass apparatus of claim 1,
where said intake tube section, said outflow tube section, and said
flow-through sliding inner tube further have the form of round
tubes.
4. The downhole fluid-pressure safety bypass apparatus of claim 1,
where said intake tube section and said outflow tube section have a
largest external-surface diameter of between 2 and 2.5 inches,
inclusive.
5. The downhole fluid-pressure safety bypass apparatus of claim 1,
where said flow-through sliding inner tube further comprises having
a central axial conduit with a tapered decreasing cross-sectional
area.
6. The downhole fluid-pressure safety bypass apparatus of claim 1,
further comprising more than one said fluid bypass port.
7. The downhole fluid-pressure safety bypass apparatus of claim 1,
further comprising more than two said fluid bypass ports.
8. The downhole fluid-pressure safety bypass apparatus of claim 1,
further comprising more than one said fluid bypass ports
distributed radially about said intake tube section.
9. The downhole fluid-pressure safety bypass apparatus of claim 1,
further comprising more than one said fluid bypass ports
distributed equidistantly about said intake tube section.
Description
CROSS-REFERENCE TO RELATED APPLICATIONS
[0001] This application is a continuation-in-part of my co-pending
application, "Downhole Pulsing Shock-Reach Extender System," filed
Dec. 28, 2016, Ser. No. 15/392,846, the full disclosure of which is
incorporated by reference and priority of which is hereby
claimed.
BACKGROUND OF THE INVENTION
[0002] This invention provides a downhole fluid-pressure safety
bypass which diverts excessively pressurized drilling fluid
directly into the annulus, protecting the fluid motor from damage
and increasing the flow of cuttings up the annulus.
[0003] In coiled-tubing operations such as drilling and workover, a
workstring of equipment is mounted on the downhole end of coiled
tubing and sent down the hole. Drilling fluid or drilling mud is
pumped downhole through the coiled tubing. A fluid motor or mud
motor is a standard component of a workstring. The fluid motor uses
drilling fluid under pressure to produce rotational force to drive
drilling or milling bits. An annulus space exists outside the
coiled tubing and the workstring. Drilling fluid is expelled by the
downhole components of the workstring for cooling and lubrication,
and for flushing cuttings back up and out of the hole.
[0004] A fluid motor or mud motor has a desired maximum pressure of
drilling fluid that it can tolerate. Above that desired maximum
pressure, the fluid motor is susceptible to damage such as
delamination and erosion of a rubber sleeve that is essential to
the proper performance of the motor. Other downhole equipment might
have similar desired maximum pressures or optimal pressures.
[0005] There might be other equipment mounted up-hole on the
workstring from the fluid motor, and that up-hole equipment might
require a drilling-fluid pressure in excess of the maximum pressure
that the fluid motor or similar downhole equipment can tolerate
without damage or reduced performance, or that up-hole equipment
might produce such excess pressure. Alternatively, there might be
no other such up-hole equipment, but pressures above the maximum
tolerable pressure might be needed for reasons like improved
flushing up the annulus, or might occur inadvertently.
[0006] There is a need for providing increased drilling-fluid
pressure up-hole from the fluid motor while preventing excessive
pressure from reaching the fluid motor.
[0007] U.S. Publ. No. 2016/0312559 was published on Oct. 27, 2016
by inventors Ilia Gotlib et al. and assignee Sclumberger Technology
Corp., and covers a "Pressure Pulse Reach Extension Technique." The
pressure pulse tool and technique allows for a reciprocating piston
at a frequency independent of a flow rate of the fluid that powers
the reciprocating. The architecture of the tool and techniques
employed may take advantage of a Coanda or other implement to
alternatingly divert fluid flow between pathways in communication
with the piston in order to attain the reciprocation. Frequency of
reciprocation may be between about 1 Hz and about 200 Hz, or other
suitably tunable ranges. Once more, the frequency may be enhanced
through periodic exposure to annular pressure. Extended reach
through use of such a pressure pulse tool and technique may exceed
about 2,000 feet.
[0008] U.S. Publ. No. 2016/0130938 was published on May 12, 2016 by
inventor Jack J. Koll and assignee Tempress Technologies, Inc., and
discloses "Seismic While Drilling System and Methods." A bottom
hole assembly is configured with a drill bit section connected to a
pulse generation section. The pulse generation section includes a
relatively long external housing, a particular housing length being
selected for the particular drilling location. The long external
housing is positioned closely adjacent to the borehole sidewalls to
thereby create a high-speed flow course between the external walls
of the housing and the borehole sidewalls. The long external
housing includes a valve cartridge assembly and optionally a shock
sub decoupler. While in operation, the valve cartridge assembly
continuously cycles and uses downhole pressure to thereby generate
seismic signal pulses that propagate to geophones or other similar
sensors on the surface. The amount of bypass allowed through the
valve assembly is selectable in combination with the long external
housing length and width to achieve the desired pulse
characteristics. The bottom hole assembly optionally includes an
acoustic baffle to attenuate wave propagation going up the drill
string.
[0009] U.S. Publ. No. 2014/0048283, published by Brian Mohon et al.
on Feb. 20, 2014, covers a "Pressure Pulse Well Tool." The
disclosure of the Mohen publication is directed to a pressure pulse
well tool, which may include an upper valve assembly configured to
move between a start position and a stop position in a housing. The
pressure pulse well tool may also include an activation valve
subassembly disposed within the upper valve assembly. The
activation valve subassembly may be configured to restrict a fluid
flow through the upper valve assembly and increase a fluid pressure
across the upper valve assembly. The pressure pulse well tool may
further include a lower valve assembly disposed inside the housing
and configured to receive the fluid flow from the upper valve
assembly. The lower valve assembly may be configured to separate
from the upper valve assembly after the upper valve assembly
reaches the stop position, causing the fluid flow to pass through
the lower valve assembly and to decrease the fluid pressure across
the upper valve assembly.
[0010] U.S. Pat. No. 8,082,941 issued Dec. 27, 2011 to Alessandro
O. Caccialupi et al. for a "Reverse Action Flow Activated Shut-Off
Valve." The Caccialupi flow-activated valve includes an outer body
and a piston disposed in an inner cavity of the outer body. The
flow-activated valve also includes one or more fluid passage exits
in the outer body and one or more piston fluid passages in the
piston. The one or more fluid passage exits and the one or more
piston fluid passages allow fluid flow out of the valve. The
flow-activated valve also includes a flow restriction member
disposed in a piston inner cavity. In addition, the flow-activated
valve includes a shear member disposed in the outer body, and a
bias member disposed in an inner cavity of the outer body. The
flow-activated valve further includes a position control member
disposed in the piston and a sealing member.
[0011] U.S. Pat. No. 7,343,982 issued to Phil Mock et al. on Mar.
18, 2008 for a "Tractor with Improved Valve System." The system
covers a hydraulically powered tractor adapted for advancement
through a borehole, and includes an elongated body, aft and forward
gripper assemblies, and a valve control assembly housed within the
elongated body. The aft and forward gripper assemblies are adapted
for selective engagement with the inner surface of the borehole.
The valve control assembly includes a gripper control valve for
directing pressurized fluid to the aft and forward gripper
assemblies. The valve control assembly also includes a propulsion
control valve for directing fluid to an aft or forward power
chamber for advancing the body relative to the actuated gripper
assembly. Aft and forward mechanically actuated valves may be
provided for controlling the position of the gripper control valve
by detective and signaling when the body has completed an
advancement stroke relative to an actuated gripper assembly. Aft
and forward sequence valves may be provided for controlling the
propulsion control valve by detecting when the gripper assemblies
become fully actuated. A pressure relief valve is preferably
provided along an input supply line for liming the pressure of the
fluid entering the valve control assembly.
[0012] U.S. Pat. No. 2,576,923, issued on Dec. 4, 1951 to Clarence
J. Coberly for a "Fluid Operated Pump with Shock Absorber," relates
in general to equipment for pumping fluid from wells and, more
particularly, to an apparatus which includes a reciprocating pump
of the fluid-operated type. A primary object of the invention is to
provide an apparatus having cushioning means associated therewith
for absorbing any fluid pressure variations which may impose
hydraulic shock loads on the system. The fluid operated pumping
unit includes a combination of (1) a source of a first fluid at a
substantially constant pressure level; (2) a receiver for a second
fluid to be pumped; (3) a pump adapted to be operating by the first
fluid to pump the second fluid; (4) a shock absorber connected to
the pump and having movable fluid separating means within it; (5)
means for a first passage communicating between the source and the
shock absorber for admitting the first fluid into the shock
absorber on one side of the fluid separating means; (6) and a
second passage means communicating between the receiver and the
shock absorber for admitting the second fluid into the shock
absorber on the opposite side of the fluid separating means.
[0013] U.S. Pat. No. 8,967,268, issued to Larry J. Urban et al. on
Mar. 3, 2015, covers "Setting Subterranean Tools with Flow
Generated Shock Wave." In the Urban patent, a circulation sub is
provided that has a ball seat and a circulation port that is closed
when a ball is landed on the seat. An axial passage directs the
pressure surge created with the landing of the ball on the seat to
the port with the actuation piston for the tool. The surge in
pressure operations the actuation piston to set the tool, which is
preferably a packer. Raising the circulation rate through a
constriction in a circulation sub breaks a shear device and allows
the restriction to shift to cover a circulation port. The pressure
surge that ensues continues through the restriction to the
actuating piston for the tool to set the tool. The Urban patent was
assigned to Baker Hughes Inc. on Nov. 30, 2011.
[0014] U.S. Pat. No. 8,939,217, issued Jan. 27, 2015 to inventor
Jack J. Koll and assignee Tempress Technologies, Inc., covers a
"Hydraulic Pulse Valve with Improved Pulse Control," pictured at
right. Hydraulic pulses are produced each time that a pulse valve
interrupts the flow of a pressurized fluid through a conduit. The
pulse valve includes an elongated housing having an inlet
configured to couple the conduit to receive the pressurized fluid,
and an outlet configured to couple to one or more tools. In the
housing, a valve assembly includes a poppet reciprocating between
open and closed positions, and a poppet seat, in which the poppet
closes to at least partially block the flow of pressurized fluid
through the valve. A pilot within the poppet moves between
disparate positions to modify fluid paths within the valve. When
the valve is open, a relatively lower pressure is produced by a
Venturi effect as the fluid flows through a throat in the poppet
seat, to provide a differential pressure used to move the pilot and
poppet. An optional bypass reduces the pulse amplitude.
SUMMARY OF THE INVENTION
[0015] This invention provides a downhole fluid-pressure safety
bypass for coiled-tubing operations, which diverts excessively
pressurized drilling fluid directly into the annulus, protecting
the fluid motor and similar downhole equipment from damage or
reduced function, while allowing greater fluid pressures to be used
up-hole for purposes such as increasing the flushing of cuttings up
the annulus.
[0016] At normal fluid pressures, all fluid flows through a
flow-through sliding inner tube which is held in a position
blocking fluid bypass ports by a calibrated coiled spring. At
excessive fluid pressures, the calibrated coiled spring is overcome
and the flow-through sliding inner tube slides into a position not
blocking the fluid bypass ports, and the excessive portion of the
fluid flow is diverted directly into the annulus.
BRIEF DESCRIPTION OF DRAWINGS
[0017] Reference will now be made to the drawings, wherein like
parts are designated by like numerals, and wherein:
[0018] FIG. 1 is a schematic view of the downhole fluid-pressure
safety bypass of the invention, in use;
[0019] FIG. 2 is a side view of the downhole fluid-pressure safety
bypass of the invention, in use;
[0020] FIG. 3 is a side view of the downhole fluid-pressure safety
bypass of the invention;
[0021] FIG. 4 is a side view showing hidden internal components of
the downhole fluid-pressure safety bypass of the invention;
[0022] FIG. 5 is an oblique partial-cutaway view of the downhole
fluid-pressure safety bypass of the invention with closed
ports;
[0023] FIG. 6 is an oblique partial-cutaway view of the downhole
fluid-pressure safety bypass of the invention with open ports;
[0024] FIG. 7 is an axial sectional view of the downhole
fluid-pressure safety bypass of the invention with closed
ports;
[0025] FIG. 8 is an axial sectional view of the downhole
fluid-pressure safety bypass of the invention with open ports;
[0026] FIG. 9 is an axial sectional schematic view of the downhole
fluid-pressure safety bypass of the invention with closed
ports;
[0027] FIG. 10 is an axial sectional schematic view of the downhole
fluid-pressure safety bypass of the invention with open ports;
and
[0028] FIG. 11 is an axial sectional view showing an internally
tapering flow-through sliding inner tube.
DETAILED DESCRIPTION OF THE DRAWINGS
[0029] Referring to FIG. 1 & FIG. 2, the downhole
fluid-pressure safety bypass 10 of the invention is intended for
use in coiled-tubing operations such as drilling and workover. The
downhole fluid-pressure safety bypass 10 is mounted on a workstring
up-hole from equipment such as a fluid motor or mud motor driving a
drilling or milling bit.
[0030] The coiled tubing and the workstring have a central axial
conduit for drilling fluid which is of a standard cross-sectional
area. For the usual round tubing, the cross-sectional area is the
internal diameter of the tubing. This standard cross-sectional area
or internal diameter is large in relation to the total area or
diameter of the tubing.
[0031] Referring to FIG. 3 & FIG. 4, the externally visible
components of the downhole fluid-pressure safety bypass 10 are an
intake tube section 1, an outflow tube section 2, and one or more
fluid bypass ports 3 located in the middle portion of the intake
tube section 1. The internal components of the downhole
fluid-pressure safety bypass 10 are a calibrated coiled spring 4
and a flow-through sliding inner tube 5.
[0032] Referring to FIG. 5, FIG. 6, FIG. 7, & FIG. 8, the
intake tube section 1 and outflow tube section 2 have a central
axial conduit for drilling fluid to flow through. The
cross-sectional area, or the diameter for standard round tubing, of
the central axial conduit changes dependent on position along the
route of flow. At the up-hole portion of the intake tube section 1
the cross-sectional area of the central axial conduit tapers down
from the standard cross-sectional area of the coiled tubing and
workstring to a smaller cross-sectional area, called the first
cross-sectional area. Fluid flowing into this portion will undergo
an increase in pressure.
[0033] The up-hole portion of the outflow tube section 2 central
axial conduit has the same or nearly the same first cross-sectional
area as the up-hole portion of the intake tube section 1. The
downhole portion of the outflow tube section 2 has an increase in
cross-sectional area, where fluid pressure will decrease before the
fluid flows into the downhole continuation of the workstring, such
as the fluid motor.
[0034] One or more fluid bypass ports 3 located in the middle
portion of the intake tube section 1 provide a path of flow out of
the central axial conduit into the annulus.
[0035] The downhole portion of the intake tube section 1 has an
increase in cross-sectional area which accommodates a calibrated
coiled spring 4 and a portion of a flow-through sliding inner tube
5. A shoulder is defined at the transition from the first
cross-sectional area to the increased cross-sectional area.
[0036] The flow-through sliding inner tube 5 has an up-hole portion
with an external size matching the first cross-sectional area of
the intake tube section 1. This portion of the flow-through sliding
inner tube 5 can slide back and forth through the up-hole portion
of the intake tube section 1. A downhole portion of the
flow-through sliding inner tube 5 has an increase in external size
matching the cross-sectional area at the downhole portion of the
intake tube section 1, and can slide within that portion. A
shoulder is defined at the transition. The flow-through sliding
inner tube 5 has a central axial conduit that is necessarily
somewhat smaller than the first cross-sectional area. When the
flow-through sliding inner tube 5 is positioned at an up-hole
extreme, with the shoulders of the central axial conduit and the
flow-through sliding inner tube 5 in contact each with the other,
the flow-through sliding inner tube 5 blocks the fluid bypass ports
3, preventing any flow of drilling fluid through those fluid bypass
ports 3. When the flow-through sliding inner tube 5 is positioned
downhole, it does not block the fluid bypass ports 3 or only
partially blocks them.
[0037] A calibrated coiled spring 4 is placed just downhole of the
flow-through sliding inner tube 5, and is held in place by the
up-hole end of the outflow tube section 2 when the intake tube
section 1 and outflow tube section 2 are joined. The calibrated
coiled spring 4 allows the flow of drilling fluid. The calibrated
coiled spring 4 presses the flow-through sliding inner tube 5
towards an up-hole extreme, where further movement is stopped by
the shoulder-to-shoulder contact. The spring is calibrated to be
overcome at a desired set pressure acting upon the flow-through
sliding inner tube 5.
[0038] Referring to FIG. 9 & FIG. 10, in use, pressurized
drilling fluid from the coiled tubing will enter the up-hole
portion of the intake tube section 1 and undergo an increase in
pressure due to the smaller first cross-sectional area of the
central axial conduit. This increased or amplified pressure is
proportional to the pressure supplied by the coiled tubing. This
amplified pressure will work upon the flow-through sliding inner
tube 5. Where the amplified pressure is at or below a level
corresponding to a desired maximum fluid pressure, the calibrated
coiled spring 4 will hold the flow-through sliding inner tube 5 at
its up-hole extreme, blocking the fluid bypass ports 3, and
channeling all of the drilling fluid through the outflow tube
section 2 an on to the downhole continuation of the workstring.
Where the amplified pressure exceeds the level corresponding to a
desired maximum fluid pressure, the counter-force of the calibrated
coiled spring 4 is overcome and the flow-through sliding inner tube
5 moves downhole, opening or partially opening the fluid bypass
ports 3, allowing a portion of the flow of drilling fluid to be
diverted into the annulus.
[0039] After passing through the flow-through sliding inner tube 5
at amplified pressure, the drilling fluid enters the larger
downhole portion of the outflow tube section 2 and undergoes a
lowering of pressure.
[0040] Referring additionally to FIG. 11, the amplified fluid
pressure operating upon the flow-through sliding inner tube 5
encounters resistance from the up-hole face and from the interior
surface of the flow-through sliding inner tube 5. This resistance
can be increased by making the cross-sectional area of the central
axial conduit through the flow-through sliding inner tube 5
smaller, either uniformly smaller or tapering down. A uniformly
smaller cross-sectional area would create a larger up-hole face on
the flow-through sliding inner tube 5, which might lead to
turbulence and wear under some conditions. A tapering transition
would not cause as much turbulence and wear.
[0041] Many changes and modifications can be made in the present
invention without departing from the spirit thereof. I therefore
pray that my rights to the present invention be limited only by the
scope of the appended claims.
* * * * *