U.S. patent application number 14/504556 was filed with the patent office on 2015-04-09 for variable high pressure transition tube set point adapter.
The applicant listed for this patent is Don Atencio. Invention is credited to Don Atencio.
Application Number | 20150096738 14/504556 |
Document ID | / |
Family ID | 52776038 |
Filed Date | 2015-04-09 |
United States Patent
Application |
20150096738 |
Kind Code |
A1 |
Atencio; Don |
April 9, 2015 |
VARIABLE HIGH PRESSURE TRANSITION TUBE SET POINT ADAPTER
Abstract
An apparatus, method, and system for inserting and securing a
high pressure transition tube of a fluid transfer tool assembly
into a positive position whereby the seal element is packed off in
the wellhead set point. Once attached the transition tube is pushed
to contact the bit guide, secondary seal or bore machine prep. A
lower nose compression seal is seated against transition tube and
compressed using an energizer seal to isolate and protect lower
pressure wellhead and well control equipment from the higher rated
frack pressures or pushing the transition tube and lower nose
isolation compression seal to contact the bit guide, secondary seal
or bore prep. Pressure is applied to push a seal against the lower
and upper compression ring locking them in place preventing
movement to form a compression seal and isolating the high pressure
passing through the transition tube protecting the wellhead
assembly and well control equipment.
Inventors: |
Atencio; Don; (Farmington,
NM) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
Atencio; Don |
Farmington |
NM |
US |
|
|
Family ID: |
52776038 |
Appl. No.: |
14/504556 |
Filed: |
October 2, 2014 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
|
|
61886192 |
Oct 3, 2013 |
|
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|
Current U.S.
Class: |
166/86.1 |
Current CPC
Class: |
E21B 34/02 20130101;
E21B 33/068 20130101 |
Class at
Publication: |
166/86.1 |
International
Class: |
E21B 34/02 20060101
E21B034/02; E21B 33/03 20060101 E21B033/03; E21B 17/00 20060101
E21B017/00 |
Claims
1. A variable valve adapter for a high pressure fracking
stimulation tool comprising: a high pressure variable transition
tube configured to make contact with a bit guide, secondary seal or
bore machine prep; a variable lower nose isolation compression seal
for seating against the high pressure variable transition tube; and
a compression apparatus to compress the high pressure variable
transition tube with the variable lower nose isolation compression
seal and isolate flowing fluids from well head control equipment.
Description
RELATED APPLICATIONS
[0001] The present application claims priority to U.S. Provisional
Application No. 61/886,192 filed Oct. 3, 2013, assigned to Assignee
hereof, and the specification of which is incorporated herein by
reference.
BACKGROUND OF THE INVENTION
[0002] 1. Field of the Invention (Technical Field)
[0003] The presently claimed invention relates to oil and gas
drilling systems, and more particularly to systems for insertion
tools, for inserting and securing a high-pressure transition tube
of a fluid/gas, and a transfer tool apparatus assembly into a
positive position in which the seal element is packed off in the
wellhead set point. The claimed invention is for the process of
fracking, a method developed and used to crack open the formation
at high pressures and to help the stimulations of oil and gas well
production, and a tool, apparatus, and a configuration equipment
and method for protecting frack containment and control equipment
and wellhead from exposure to pressures higher than the pre-design
operating range and from the abrasive and or corrosive fluids
during well fracturing and pumping procedures.
[0004] 2. Background Art
[0005] Wells require some form of stimulation called fracking to
stimulate production and make or keep them productive. The fracking
of oil and gas wells formations to stimulate production requires
that high pressure pumping equipment be used to inject fluids,
chemicals, and sands at high pressures. The frack fluids are
generally corrosive and abrasive because of acids and abrasives
used to open cracks in the formations with special sand.
[0006] New technology and methods as well as safety and
environmental regulations that are being adopted industry wide
cannot be accomplished with the lower pressure frack containment
equipment, Blowout Preventers (BOPs) or through a valve attached to
the wellhead. The practice of fracking or pumping through BOPs
equipment, valves or wellheads at pressures higher that the
pre-engineered design pressure rating has been determined to be
unsafe and is no longer Standard Operating Practice (SOP).
[0007] This method was adopted because it was the only way to have
full access to a well casing bore with down-hole tools during the
well fracking or servicing. The industry's known methods and
technologies indicate that new methods must be developed to acquire
full bore access to well bore at much higher pressures. Full bore
access to the casing permits use of down-hole tools that are often
required during a frack stimulation treatment without having to
remove tools or equipment between multi-stage frack stimulation, as
was required with older style conventional wellhead isolation tools
such as disclosed in U.S. Pat. No. 4,867,243, entitled WELLHEAD
ISOLATION TOOL AND SETTING AND METHOD OF USING SAME.
[0008] An apparatus for providing full access to the casing while
permitting stimulation treatments at extreme pressures that
approach a burst pressure rating of the casing is described in U.S.
Pat. No. 6,289,993, entitled BLOWOUT PREVENTER PROTECTION AND
SETTING TOOL.
[0009] Another prior art reference describes an apparatus and
method of isolating a well tree located on an oil or gas well from
the effects of high pressure or corrosion caused by stimulation of
a well is described in U.S. Pat. No. 4,867,243 entitled WELLHEAD
ISOLATION TOOL AND SETTING TOOL AND METHOD OF USING SAME. This
reference describes an apparatus to permit the injection of fluids,
gases, solid particles, or mixtures through a well tree while
protecting the well tree during well stimulation treatments. The
apparatus includes a single hydraulic cylinder supported in an
axial alignment over a well tree by at least two elongated support
rods. The hydraulic cylinder support rods are connected between a
base plate and a hydraulic cylinder support plate for supporting
the hydraulic cylinder above the well tree at a distance
approximately equal to the height of the production tree.
[0010] This device permits the insertion of a single length of high
pressure tubing through any well tree regardless of its height.
Once the high-pressure tubing is seated in a well tubing or casing,
the hydraulic cylinder, hydraulic cylinder plate, and support rods
are removed to provide 360.degree. access to a high-pressure valve
attached to the top of the high-pressure tubing. The bottom end of
the high-pressure tubing has a packoff nipple assembly that is
inserted into the production tubing or casing and seals against the
inner wall. Thus, the extent to which the high pressure tubing
extends into the production tubing or casing is unimportant so long
as the packoff nipple assembly is sealed against the inner wall.
Consequently, variations in the length of the production tree are
of no consequence and a lockdown mechanism with a short reach is
adequate. Therefore, there exists a need for a mechanical lockdown
mechanism that provides a broad range of adjustment to permit
packoff with a fixed packoff surface in a wellhead.
SUMMARY OF THE INVENTION
[0011] The presently claimed invention overcomes the shortcomings
of the prior art by providing a locking mechanism, described as a
variable adjuster locking sleeve, which houses and forms a barrier
around a high pressure transition tube. The variable adjusting
locking sleeve is capable of up and down vertical movement while
simultaneously providing a pressurized barrier around the variable
high pressure transition tube and in the unibody master housing
with test ports to verify seal integrity. Additionally, the
presently claimed invention prevents exposure of the barrel, which
creates safety and environmental hazards if a breach or internal
wash or damage occurs.
[0012] When the mechanical locking mechanisms are attached or
applied, the variable adjuster sleeve houses the high pressure
variable transition tube and assembly to achieve a double barrier
pressure seal and a double retention locking ring, which are not
available in prior art. The claimed invention greatly improves the
art of wellhead equipment isolation tools and the protection from
high pressures, corrosive chemicals, and abrasive sand to-well
control equipment, blowout preventers (BOPs), flow control valves,
flow spools other equipment known in the industry by sealing and
protecting from high well pump frack stimulation pressures, and to
overcome the design shortcomings, safety and environmental concerns
of the prior art.
[0013] It is the intention of the presently claimed invention to
provide an isolation seal barrier for protection of well control
equipment and safe operation for personnel and environmental
protection while still accessing high-pressure fracking technology
during the well stimulation process and treatment.
[0014] It is also a further object of the presently claimed
invention to provide an isolation seal barrier for protection from
high pressures, corrosive chemicals, and abrasive sand-to-well
control equipment such as blowout preventers (BOPs), flow control
valves that are secured and locked into position by a mechanical
locking mechanism capable of sealing and providing a pressure
protection barrier. It is a further object of the present invention
to provide a safety and environmental protection to personnel and
environment through engineering design.
[0015] In accordance with one aspect of the presently claimed
invention, there is provided, an apparatus for protecting well
control equipment from exposure to fluid pressures, abrasives, and
corrosive fluids used in well treatment to stimulate production.
The apparatus comprises a high pressure transition tube adapted to
be inserted down through the well control equipment to an operative
position. The high pressure transition tube has a top end and a
bottom end, the high pressure transition tube bottom end including
prep for a hollow nose bullet sealing assembly for sealing
engagement in the wellhead casing seal with a top metal energizer
ring seated on top of the casing seal bit guide. The assembly is
compressed when weight or force is introduced compressing the seal
between the steel energizer rings, thus, forcing an elastomer seal
to compress and expand outward against the wall of the wellhead
bore, thus, eliminating the need to have a controlled tolerance or
pre-engineered measurements or dimensions such as are needed with
o-ring style seals.
[0016] When the high pressure transition tube and hollow nose
bullet seal are in the operative position, a mechanical lockdown
mechanism detachably secures the high pressure transition tube to
the well control equipment. The lockdown mechanism being adapted to
ensure that the hollow nose seal assembly sealing body is securely
seated against the top of the casing and in the wellhead secondary
seal when the high pressure transition tube is in the operative
position. The mechanical lockdown mechanism preferably includes a
variable adjuster locking sleeve, high pressure variable transition
tube, hollow nose seal assembly, and a unibody master housing that
is manufactured to universal API 6A standards. The variable high
pressure transition tube mechanical lockdown mechanism is mounted
to a top of the well control equipment, and the variable tube
housing adapter has a centered passage port to permit the
installation and removal of the variable tube. The passage port
provides housing for the high pressure variable tube sleeve that
has machined thread for engaging the high pressure variable tube
and a high pressure adapter or well control valve. The high
pressure adapter or well control valve is adapted to secure and
retain the high pressure tube and high pressure variable seal
assembly in the operative position. The variable transition tube
spiral thread length is adequate to ensure positive retention and
safe operation at well stimulation fluid pressures such as 10,000
to 15,000 Pounds per Square Inch (PSI).
[0017] The high pressure variable pass-through tube has at least
one external and one internal spiral thread, and one on the high
pressure variable transition tube adjuster adapter. The high
pressure variable transition tube adjuster adapter has a length
adequate to provide a significant range of adjustment, preferably
at least about 5'' (12.5 cm), to compensate for variations in a
distance between a top of the closing equipment (valve and/or BOP),
the secondary seal assembly, and bore wall of the tubing head
assembly, where the high pressure variable seal assembly inserts
into the casing seal prep profile and packs off. The mandrel may be
cycled in and passed through the well control equipment using any
type of mechanical push/pull mechanism for the insertion of high
pressure variable tube assembly or wellhead saver. Once inserted,
the high pressure variable tube assembly is securely locked in its
operative position by adjusting the variable adjustment pressure
adapter until it contacts the frack adapter head retainer
mechanical locking mechanism, and is locked in the optimum
position.
[0018] The presently claimed invention provides a method for
protecting the tubing head wellhead assembly, well control
equipment, and other equipment from exposure to abrasive, and
corrosive fluids and pressures above the intended manufactured
design during a well frack and stimulation process. The tool
assembly comprises a variable high pressure transition tube, a
unibody high pressure transition valve or frack valve adapter head
designed to be inserted down through the well control equipment and
connected to a top end variable adjuster locking sleeve adapter.
The unibody high pressure transition valve or valve adapter head is
adapted to and connected to the variable high pressure transition
tube and protrudes above the unibody master housing, well control
equipment, and the variable high pressure transition hollow nose
bull seal. The variable high pressure transition hollow nose bull
seal assembly end includes a wellhead through bore wall elastomer
compression seal and at least one sliding sleeve energizer ring
when inserted for sealing with a secondary back up compression
energized seal. The secondary compression energized seal compresses
with force against the wellhead through bore wall when the hollow
nose bullet seal assembly and variable high pressure transition
tube are locked into position.
[0019] A mechanical push/pull insertion mechanism is used for
inserting the variable high pressure tube into and removes the
variable high pressure tube in and out of the well control
equipment. The mechanical push/pull insertion mechanism is
supported by at least two elongated variable shank rods attached to
the unibody master housing shank rod plate and integrated API
flange. The unibody master housing API flange is sized to mate to
the well control equipment for supporting the mechanical push/pull
insertion mechanism in vertical and axial position set above the
well control equipment and high pressure transition tube unibody
master housing and shank rod plate. The shank rods and the
mechanical push/pull mechanism are removable once the unibody
pressure transition valve and variable high pressure transition
tube and hollow nose bullet seal assembly are inserted through the
well control equipment.
[0020] A primary advantage of the presently claimed invention is
the use of a variable adjuster locking sleeve adapter. The variable
adjuster locking sleeve adapter locking mechanism has several
advantages that make it superior to the prior art. One primary
advantage is the double barrier design that encapsulates and houses
the variable high pressure transition tube, whereby the variable
adjuster locking sleeve adapter allows the high pressure variable
tube to pass and slide through, and up and down while maintaining a
back pressure seal during the in and out installation process.
[0021] Another advantage of the presently claimed invention is that
the high pressure transition tube is completely housed and sealed
by the variable adjuster locking assembly. The variable adjuster
locking sleeve adapter is designed with internal and external seals
that can be externally hydraulically tested for seal integrity.
[0022] Another advantage not available in prior art is that the
variable adjuster locking sleeve adapter is also fitted with metal
to metal ring seal, that once locked down into place forms a double
barrier seal. This is optimal because even if the high pressure
variable tube is damaged, breached, or washed through, it is
contained within the outer shell of the variable adjuster assembly
with seals the contain pressure internally to safely protect
personnel and the environment.
[0023] Other advantages of the presently claimed invention are
quick connecting double retention for rods and low profile for easy
access to well control equipment. In addition, the security
provided by a mechanical double lockdown mechanism is independent
and provides a back-up lock further securing to ensure retention of
the high pressure transition tube that eliminates safety and
environmental concerns.
[0024] Other advantages include the ability to pressure test high
pressure transition tube seals for integrity, and a removable shank
rod plate and adjustable shank rods are configured to fit different
variations of equipment lengths, which reduces cost and offers
versatility.
[0025] Furthermore, the separable shank plate's adjustable rods,
the quick connect guides, and removable insertion tool reduces
manufacturing and maintenance costs of the apparatus.
BRIEF DESCRIPTION OF THE DRAWINGS
[0026] The accompanying drawings, which are incorporated into and
form a part of the specification, illustrate several embodiments of
the presently claimed invention, and together with the description,
serve to explain the principles of the presently claimed invention.
The drawings are only for the purpose of illustrating a preferred
embodiment of the claimed invention and are not to be construed as
limiting the presently claimed invention.
[0027] FIG. 1-1 shows the top half of a cross-sectional exploded
view of the preferred unibody master housing assembly with variable
adjuster locking sleeve adapter assembly viewed in various
positions of vertical installation positions. FIG. 1-1 also shows
the variable high pressure transition tube in an exploded view
inserted into the pressure transition control valve. It features
the external test ports for testing pressure transition tube seals
and locking mechanism metal seal, shank plate and locking ring
installed in the master housing, backup variable adjuster locking
sleeve adapter retainer ring, with internal and external tube seals
with upper and lower test ports to test seal integrity of unibody
master housing and pressure transition tube.
[0028] FIG. 1-2 is the bottom half of the cross-sectional exploded
view of the preferred high pressure variable tube assembly with the
hollow bullet nose seal assembly installed in the variable tube and
inserted into the wellhead casing secondary seal. FIG. 1-2
illustrates the metal energizer compression ring seated to the top
of the secondary seal bit guide, the elastomer compression seal
protruding or pushing outwards as force is applied to compress
against the bore wall of the wellhead and two different forms of
seals working simultaneously.
[0029] FIG. 2 is a cross-sectional view of the variable adjuster
locking assembly and unibody master housing assembly with variable
adjuster locking sleeve assembly disengaged as shown in FIGS. 1-1
and 1-2. It also illustrates the variable high pressure transition
extracting out and away from the disengaged variable adjuster
locking sleeve and traveling up in a vertical path away from the
unibody master housing and traveling through the variable adjuster
locking sleeve adapter and seals. FIG. 2 also illustrates how the
secondary locking ring works independent of the primary locking
assembly.
[0030] FIG. 3 is a front view of unibody master housing assembly
cross section with high-pressure variable transition tube and quick
connect shank rod connection assembly mounted to the shank rod
plate with shank rod inserted and securely locked into position
with a safety back up lock nut installed.
[0031] FIG. 4 is an alternate flanged frack valve adapter
embodiment to the unibody pressure transition control valve adapter
and locking clamp mechanism used in the high pressure transition
tube well control equipment protector.
[0032] FIG. 5-1 is a front view of the variable high pressure
transition tool assembly mounted on well control equipment with the
upper and lower shank rod plate assemblies and ram assembly mounted
to the shank rod plate with variable adjustable shank rods.
[0033] FIG. 5-2 is a partial cross-sectional view of a variable
high pressure transition tube and an embodiment of seal assembly
inserted and attached to a variable high pressure transition tube
for sealing against an inner wall of well control equipment.
[0034] FIG. 6 is a partial cross-sectional view of an alternate
preferred embodiment of an annular sealing body for sealing against
the inner wall. It is inserted into a preinstalled casing sealing
assembly that is inserted and installed to the casing and mounted
and secured in the well control equipment.
[0035] FIG. 7 is a partial cross-sectional view of an alternate
preferred embodiment of an annular sealing body for sealing against
the inner wall of the well control equipment with a metal to metal
compression ring that seats or butts up to the tool guide of the
casing seal. It is then compressed by force, which preloads and
energizes the seal or seals against the inner wall of well control
equipment to positively provide a seal.
[0036] FIG. 8 is an embodiment of an alternate seal of FIG. 5-2
illustrating a metal ring in contact with a casing secondary seal
bit guide used to energize an elastomer or polyurethane seal when
pressure is applied and used to compress the seal against the body
of the wellhead bore. This force pushes the seal outward against
the bore, which does not require controlled tolerances.
DESCRIPTION OF THE PREFERRED EMBODIMENTS
Best Modes for Carrying Out the Invention
[0037] FIGS. 1-1 and 1-2 show a cross-sectional view of the
variable high pressure transition tool for protecting the wellhead
control equipment (hereinafter referred to as variable pressure
isolation tool) 10. Variable pressure isolation tool 10 includes a
unibody master housing 12, a shank rod plate 14 that is drilled,
tapped, and prepped with bolt threads uniformly positioned around
the radius of shank rod plate 14. Shank rod plate bolts 18 are
affixed to shank rod plate 14 and to split locking ring 16 that are
then placed into position on unibody master housing 12 by sliding
shank rod plate 14 over the top of upper member of unibody master
housing 12. Unibody master housing 12 can also include at least two
or more split retainer rings 20 that include bolt holes around the
radius of split locking ring 16 with vertically aligning holes in
shank rod plate 14. Split locking rings 16 are inserted into
position in unibody master housing locking ring slot groove 22,
shank rod plate 14 is lifted into position, and the hole aligned
with split locking ring 12. One or more shank rod plate bolts 18
are inserted into the aligned holes and rotated into retainer ring
bolt threads 24 and tightened or torqued into position. Unibody
master housing 12 is machined and configured with a tube seal
pocket 26, fitted and sized with seal 30 interference against the
vertical wall of variable tube seal pocket prep 26 that will accept
one or more tube seals 30. Variable high pressure transition tube
32 is inserted into and through vertical bore 34 of unibody master
housing 12 and one or more tube seals 30 are inserted and placed
into position around variable high pressure transition tube 32.
Packing retainer ring 36 is placed around variable high pressure
transition tube 32 and slid into position until packing retainer
ring 36 makes contact with retainer ring threads 38, and is then
rotated into position and locked in place. Variable high pressure
transition tube 32 is fitted and prepped with male High Pressure
(HP) nose seal prep 42. HP nose seal prep 42 is fitted with at
least one or more high pressure tube seals 44 with spiral threads
46 to engage with complementary unibody pressure transition control
valve spiral threads 48 and tube bore 50. Tube bore 50 should be
large enough to provide full access to the well bore casing as
shown in FIG. 2. Spiral threads 56 are used to engage with variable
high pressure transition tube complementary spiral threads 58 and
at least one tube seal upper 60 and a lower outer variable tube
seal 62. Unibody pressure transition control valve 52 has a
variable tube test port 64 that enables testing from 10,000 to
15,000 PSI on tube seal upper 44, and lower outer variable tube
seals lower 62 for safety and seal integrity. Unibody pressure
transition control valve 52 is prepped with integrated locking
clamp preparation 66 flanged or winged hub (not shown).
[0038] Variable high pressure transition isolation tool assembly 32
is also adapted with a variable adjuster locking sleeve 70 with
spiral variable adjustable threads 28 that are provided externally
for adjusting the sleeve up or down 92 into position to mate with
the setting position of a unibody pressure transition control valve
52 and variable high pressure transition tube 32. Variable adjuster
locking sleeve 70 is fitted with inner tube seal 100 and outer seal
102 to prevent escape or spill of any pressurized liquids that
might be present should seal 78 and tube seal 30 be damaged or have
hollow nose bullet seal body assemblies 94 that are mated with
wellhead seal prep 86 leak. Hollow nose bullet seal body assembly
94 is fitted with external complementary spiral threads 56 and
internal complimentary threads 58 that have at least one external
elastomer seal 78 and lower energizer ring 80. Lower energizer ring
80 is installed by placing it over and sliding the upper external
threads 56 and lowering it to no go stop 84. Elastomer compression
seal 78 and upper energizer ring 82 are installed using the same
steps.
[0039] Bullet nose hollow seal assembly 94 is installed into
variable high pressure transition tube 32 by rotating complementary
threads 56 and 58 until hollow nose bullet seal assembly 94 stops
rotating and is fully engaged. When bullet nose hollow seal
assembly 94 engages and is set inside wellhead seal prep 86 with
lower energizer ring 80, it stops on top of wellhead seal bit guide
88. Force is applied by means of weight or hydraulic (not shown) to
the top of variable high pressure transition tool 10 which forces
upper energizer ring 82 to push against elastomer compression seal
78 and lower energizer ring 80 compressing and preloading the seal
against the wellhead vertical wall. Variable adjuster locking
sleeve 70 is usually pre-set to the lowest operation position of
variable adjustment 74 by rotating clockwise or counter clockwise
on threads 28 of the variable adjuster tube sleeve and master
housing thread 29 to match the final optimum setting position of
hollow nose seal assembly 94 and unibody pressure transition valve
52. Locking clamp 68 flange or winged connection (not shown) is
installed and locked in the optimum position and clamp bolts 96 are
installed and secured into position.
[0040] Variable adjuster locking sleeve 70 is fitted with
well-known types or methods for locking clamping or bolting hub
prep 68 and fitted with steel seal ring prep 40 as a backup
pressure containment barrier if lower tube seal 102, 78 fails.
Variable adjuster locking sleeve 70 is fitted with an inner seal
100 and outer seal 102 master housing seal 98 to prevent exposure
and spills should tube seal 102, hollow bullet nose seals 76, or
compression seal 78, and master housing seal 30 fail. Variable
adjuster locking sleeve 70 also provides a passage bore for
variable high pressure transition tube 32 to pass through and
travel up and down or in and out of locking sleeve barrier bore
104. Variable adjuster locking sleeve 70 is fitted with an upper
test port 106 to test master housing outer locking sleeve seal 98,
102 for seal integrity. Lower test port 108 provides for testing
locking sleeve inner seal 100 and tube seal 30 for seal
integrity.
[0041] FIGS. 2 and 3 illustrate the variable high pressure
transition tool of FIGS. 1-1 and 1-2, prior to being mounted above
well control equipment for a well stimulation treatment. Locking
clamp 68 is removed from variable adjuster locking sleeve 70 and
the lockdown mechanism is disengaged from unibody high pressure
control valve 52 and away from unibody master housing 118. Rod
shank plate 14 and unibody high pressure control valve 52 are
connected to the top end of variable high pressure transition tube
32, which includes any required proper variable high pressure
transition tube length section(s) and hollow nose bullet seal
packoff assembly 76 to provide a total length required for a
particular well control equipment or wellhead. Unibody master
housing 118 is mounted on the top end of the well control equipment
or BOP and the combination of unibody high pressure control valve
52 with lockdown clamp 68 and variable high pressure transition
tube 32, are inserted from the top into the well control equipment
or BOP using any one of several insertion tools known in the
industry. Rod shank plate 14 is fitted with at least two or more
rod quick connect assemblies 120 for attaching upper rod shank
plate (not shown) and lower rod shank plate 14, at least two or
more variable rod shanks 122, and at least two or more rod safety
nuts 124 for backup security while inserting or pulling under
pressure.
[0042] FIG. 4 illustrates a flanged end valve adapter 128 fitted
and prepped with a female HP nose seal prep 42. Flanged end valve
adapter 128 has spiral threads 46 to engage with variable high
pressure transition tube complementary spiral threads 48 that have
at least one tube seal upper 44 and lower outer variable tube 32.
Flanged end valve adapter 128 has a variable tube test port 64 that
enables testing of 10,000 to 15,000 PSI on tube seal upper 44 and
outer variable tube seals lower 62 for safety and seal integrity.
Flanged end valve adapter 128 is prepped with integrated locking
clamp 66 flanged or winged hub (not shown).
[0043] The variable high pressure transition tool in FIGS. 5-1 and
5-2 illustrates an example of the use of well control equipment and
wellhead protector 10, shown in FIGS. 1-1 and 1-2, using a
hydraulic setting tool as described in U.S. Pat. No. 4,867,243,
which is incorporated herein by reference. The tool is connected to
casing well bore by various casing methods that are well known in
the industry using equipment such as a tubing head and tubing
spool. Well control equipment are parts and devices known in the
oil and gas industry as wellhead equipment, wellhead components and
parts, blow out preventers that are also well known in the oil and
gas industry and not described in this disclosure. Mounted above
the wellhead assembly is the well control equipment that is used
for pressure and fluid flow control during the fracking procedure
and well treatment. The equipment is also used to secure and
prevent well fluids from escaping into the atmosphere.
[0044] FIG. 5-1 shows variable high pressure transition tool
assembly 10 mounted to well control equipment 140, unibody high
pressure frack valve 52 mounted to the top of variable high
pressure transition tube 32 to control well pressure and or fluid
during the insertion and removal of variable high pressure
transition tube 32 to prevent well fluids from escaping to
atmosphere. FIG. 5-1 shows the system before variable high pressure
transition tool 10 is installed or removed. High pressure valve 52
is hydraulically or manually operated or controlled. Hydraulic
setting tool 136 includes a hydraulic cylinder, which is mounted to
upper rod shank plate 132. Upper shank rod plate 132 includes
passage 133 to permit a piston rod for hydraulic cylinder 138 to
pass through upper shank rod plate 14. Upper shank rod plate 132
also includes at least two attachment points 135 for attachment of
variable rod shank 122 to shank rod plate 14. Variable rod shank
attachment points 135 are preferably equally spaced from central
bore 133 to ensure that the hydraulic cylinder and the piston rod
align with unibody pressure transition control valve 52 to which
the hydraulic cylinder attachment (not shown) is mounted. The
hydraulic cylinder and variable rod shank 122 are respectively
attached on their lower shank rod plate 14 ends at corresponding
attachment points on the plate, which is mounted to the top of well
control equipment 140. Lower shank rod plate 14 is supported by two
or more variable rod shanks 122 that are identical in length and
are manufactured with course threads described as variable rod
shank adjustment threads 130. This permits the upward or downward
adjustment of upper shank rod plate 132 by rotating adjustment nuts
130 to accommodate variations in lengths or size of equipment.
Shank rods 122 are attached to the respective attachment points 135
and 120 on upper shank rod plate 132 and lower shank rod plate 14
by means of rod quick connect assembly 120 comprising of threads or
pins and nuts (not shown).
[0045] Piston polish rod 133 is attached to the top of the high
pressure valve 52 by a connector so that mechanical force can be
applied by pushing and applying force to top of unibody wireline
valve adapter of well control to well control equipment 140
protector and the attached high pressure valve to stroke them in
and out of the wellhead. When variable high pressure transition
tube 32 is in the operative position shown in FIG. 5-2, the bottom
end of metal energizer ring assembly 80 is in contact with a bit
guide 88 attached to a top of casing wellhead seal 144. Bit guide
88 covers casing 145 to protect the top end of casing 145 and
provides a seal between casing 145 and wellhead assembly 142 in a
manner well known in the industry as a secondary seal or wellhead
seal 144.
[0046] As noted above, variable high pressure transition tube 32
has a variable length adjustment 74 as illustrated FIG. 1-1, so
that hollow nose seal assembly 94, including upper compression seal
ring 82, compression packoff 78, and lower compression ring 80,
have adequate length to ensure that the top end of variable
adjuster locking sleeve 70 extends above the top of unibody master
housing 22 with just enough up and down adjustment 74 to rotate and
contact with unibody pressure transition valve 52. Hollow nose seal
assembly 94 is secured by lockdown assembly clamp 68 described
above when packoff assembly 62 is seated against bit guide 94.
However, the distance from the top of bit guide 94 and the top of
well control equipment 74 may vary to some extent in different
wellheads. This variation cannot be accommodated by a conventional
lockdown mechanism such as taught in Applicant's U.S. Pat. No.
4,867,243. The presently claimed invention overcomes this
shortcoming.
[0047] FIG. 6 shows hollow bullet nose seal assembly 94, which
comprises four parts with a unique design that eliminates the need
for a retainer ring or no go. The assembly has a lower ring 80,
known as the lower energizer ring, which seats or contacts the top
of wellhead secondary seal 88, known as the wellhead bit guide.
Lower energizer ring 80 is installed over bullet nose 94 and thread
58 and slid down to no go stop 84. Compression seal 78 is installed
by placing it over the top of the bullet nose seal and then slipped
over threads 58 to lower energizer ring 80. Upper energizer seal
ring is also slipped over the top of bullet nose 94 and threads 58
until it contacts compression seal 78. Hollow bullet nose seal
assembly 94 is now installed to the bottom of high pressure
variable transition tube 32, as shown in FIG. 1-2
[0048] As shown in FIG. 7, hollow bullet nose seal assembly 94 is
comprised of four parts with a unique design that eliminates the
need for a retainer ring or no go. The assembly has a lower ring
148, known as the lower energizer ring that seats or contacts the
top of wellhead secondary seal 88 (not shown), known as the
wellhead bit guide. Lower energizer ring 148 is designed with a
radius taper positioned to force elastomer seal 146 outward to
force compression against the outer wall of the wellhead through
bore as illustrated in FIG. 5-2. The more force that is applied,
the tighter the seal is applied to the bore wall ensuring a
compression seal. Compression seal 146 is installed over the nose
and thread 58 and slid down to no go stop 84. Compression seal 146
is installed by placing it over the top of the bullet nose seal and
slipped over threads 58 to lower energizer ring 148. The radius
taper design of compression seal 148 matches the radius taper of
bottom seal energizer ring 146. Upper energizer seal ring 82 is
also slipped over the top of bullet nose 94 and threads 58 until it
contacts compression seal 146. Hollow bullet nose seal assembly 94
is now installed to the bottom of high pressure variable transition
tube 32 as shown in FIG. 1-2.
[0049] FIG. 8 is an embodiment of an alternate seal as shown FIG.
5-2. FIG. 8 illustrates a metal energizer ring in contact with a
casing secondary seal bit guide 88 used to energize an elastomer or
polyurethane seal 78 when force is applied and used to compress the
seal against the body of the wellhead bore known in the industry as
a through bore. This force pushes the seal outward against the
bore, which does not require a controlled tolerance or measurement,
as in prior art energizer rings. Polyurethane seal 78 is equipped
with an outer seal prep 154 and an inner seal prep 152 (not shown),
these seals serve to pressure energize the compression seal 78
without the need for compression. Compression is achieved by inner
bore pressure, which forces the compression of seal 78. The more
pressure, the more compression, and the tighter the seal. Bullet
nose seal 94 is inserted and rotated into position by spiral
threads 46 and complimentary threads 48 into high pressure tube
where seals 44 contact high pressure inner wall seal prep. Bore of
tube 50 is equal to casing wall 156 which gives the user full
access to the well bore allowing tools to be inserted in and out of
the well
[0050] Although the claimed invention has been described in detail
with particular reference to these preferred embodiments, other
embodiments can achieve the same results. Variations and
modifications of the presently claimed invention will be obvious to
those skilled in the art and it is intended to cover in all such
modifications and equivalents. The entire disclosures of all
references, applications, patents, and publications cited above,
are hereby incorporated by reference.
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