WO2016160108A1 - Method and apparatus for inserting a tubular string into a well - Google Patents
Method and apparatus for inserting a tubular string into a well Download PDFInfo
- Publication number
- WO2016160108A1 WO2016160108A1 PCT/US2016/015169 US2016015169W WO2016160108A1 WO 2016160108 A1 WO2016160108 A1 WO 2016160108A1 US 2016015169 W US2016015169 W US 2016015169W WO 2016160108 A1 WO2016160108 A1 WO 2016160108A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- housing
- spring
- spring housing
- flow tube
- flapper
- Prior art date
Links
- 238000000034 method Methods 0.000 title claims abstract description 7
- 238000002955 isolation Methods 0.000 claims abstract description 13
- 230000004044 response Effects 0.000 claims description 5
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims description 4
- 229910052757 nitrogen Inorganic materials 0.000 claims description 2
- 239000007789 gas Substances 0.000 claims 2
- 230000004888 barrier function Effects 0.000 abstract description 9
- 239000012530 fluid Substances 0.000 abstract description 2
- 238000007789 sealing Methods 0.000 description 6
- 238000005553 drilling Methods 0.000 description 3
- 238000010008 shearing Methods 0.000 description 3
- 239000004568 cement Substances 0.000 description 2
- 239000007788 liquid Substances 0.000 description 2
- 230000008569 process Effects 0.000 description 2
- 239000002002 slurry Substances 0.000 description 2
- 230000002457 bidirectional effect Effects 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 230000006835 compression Effects 0.000 description 1
- 238000007906 compression Methods 0.000 description 1
- 230000008878 coupling Effects 0.000 description 1
- 238000010168 coupling process Methods 0.000 description 1
- 238000005859 coupling reaction Methods 0.000 description 1
- 238000006073 displacement reaction Methods 0.000 description 1
- 230000009977 dual effect Effects 0.000 description 1
- 229920001971 elastomer Polymers 0.000 description 1
- 239000000806 elastomer Substances 0.000 description 1
- 238000005188 flotation Methods 0.000 description 1
- 230000002706 hydrostatic effect Effects 0.000 description 1
- 230000014759 maintenance of location Effects 0.000 description 1
- 230000007246 mechanism Effects 0.000 description 1
- 239000003566 sealing material Substances 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
- 230000035939 shock Effects 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/06—Valve arrangements for boreholes or wells in wells
- E21B34/14—Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/06—Valve arrangements for boreholes or wells in wells
- E21B34/10—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
- E21B34/102—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole with means for locking the closing element in open or closed position
- E21B34/103—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole with means for locking the closing element in open or closed position with a shear pin
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
- E21B2200/05—Flapper valves
Definitions
- This invention relates to a differential pressure- activated valve in a sub to be placed in a tubular of a well before the tubular is placed in the well. More particularly, a barrier valve in a sub is provided to seal pressure in both directions, to open in response to a pressure applied uphole, to provide a full opening diameter of the tubular and to be locked in the open position.
- Valves are used in diverse applications in the tubulars of wells.
- Tubulars includes casing, liners and tubing.
- safety valves are placed in tubing that are designed to close if flow upward through the tubing is otherwise uncontrolled.
- Sliding sleeves to form valves are placed in casing to be opened or shut by devices placed inside the casing, and valves are placed in casing or tubing of complex (or "smart") wells to control flow rate from different laterals of the well.
- Examples of valves for wells are in U.S. Pat No. 8,622,336 and in U.S. Pat No. 8,757,268. Further examples of valves to be inserted in tubulars are provided in U.S. Pub. No.
- valve used in casing is a "float valve,” which is used at the shoe
- a float valve is normally a simple ball check valve.
- the float valve may also be used in the process of "floating" casing into a well. "Floating" casing is used to allow casing to be placed in horizontal wells with less weight of the casing and less frictional resistance as the casing is placed in a horizontal segment of a well.
- Floating casing is accomplished by placing nitrogen or air inside the casing to decrease the weight of the casing. This facilitates inserting the casing over longer horizontal sections.
- One operator's experience with "floating" a tubular into a well is described in the paper “Statoil uses flotation of 10 3 ⁇ 4-in, liner to reach beyond 10 km in Gullfaks Field," Drilling Contractor, May/June 2007, pp. 66-74. [0004]
- Leaks in the tubular may occur that allow liquid to enter the tubular and result in the casing or liner becoming stuck in the well before it is properly placed.
- a valve that can be placed at selected locations along a tubular string and opened to the full diameter of the tubular by a pressure increase at the surface of the tubular is needed.
- a series of valves each of which may be called a “cascade barrier valve,” may be preferred. This valve, when open, should allow movement of downhole tools through the tubular without restriction.
- cascade barrier valves at selected locations along the casing may be used to prevent fluid leaking in and filling a long interval of the casing while it is being floated into a horizontal well.
- Valves in tubulars in wells that form a pressure barrier until opened by a surface operation and then are locked open to provide full inside diameter also offer wide opportunities for increasing well safety.
- a full-opening valve in a sub for placement in a string of casing, liner or tubing that is opened by a selected pressure applied from the surface is provided.
- a shear ring or pin is selected to shear at a selected differential pressure in response to a pressure increase at the surface and allows a lower flow tube having the inside diameter of the tubular to move axially.
- the flapper is locked in the open position for the life of the valve by operation of the upper flow tube and a snap ring, which locks the upper flow tube in position over the open flapper.
- the valve may be used to provide a pressure barrier in the casing during floating of the casing into a horizontal well or after the casing is in place or it may be used in tubing to prevent flow in the tubing in either direction until a selected pressure is applied at the surface.
- Valves may be adapted to open at a differential pressure across the valve which varies over a broad range of differential pressures within the operating pressure of the valve.
- the valve may be closed during deployment and once activated is locked in the open position.
- the isolation valve may be used by itself to provide a barrier in either the casing or the tubing, or may be used in conjunction with additional valves to form chambers in the tubular string.
- FIG. 1 is a cross-section view of valve sub 10 in the closed or run-in condition.
- FIG. 2 is a cross-section view of valve sub 10 after shearing of a disk or pin and before opening of the flapper.
- FIG. 3 is a cross-section view of valve sub 10 in the open position.
- FIG. 4 is a cross-sectional view of the valve sub 10 at cross-section "4" in
- FIG. 5 is an isometric view of the flapper in closed position with outer parts removed from the drawing.
- FIG. 6 is an isometric view of the flapper in the partially-open position with outer parts removed from the drawing, identifying upper and lower sealing surfaces on the flapper.
- FIG. 7 is an isometric view of the flapper in open position with outer parts removed from the drawing.
- FIG. 8 is a perspective view of the flapper.
- FIG. 9 is a side view of the flapper positioned between the upper and lower flow tube.
- isolation valve 10 has lock housing 12, which is adapted to be joined in a tubular string, normally by pipe treads (not shown) and which preferably has the same inside diameter as the tubular string.
- the outside diameter of the isolating valve is not more than the outside diameter of couplings in the tubular string.
- Seal 13 provides a barrier between lock housing 12 and upper spring housing 15.
- Upper flow tube 18 preferably has the same inside diameter as the minimum inside diameter of lock housing 12 and is adapted to slide within upper spring housing 15.
- Upper flow tube 18 may have internal shifting profile 11. Shifting profile 11 may be used for optional manual shifting to open flapper 24 and allow intervention from uphole by jarring or other mechanical force if isolation valve 10 is not operating properly.
- Shifting profile 11a may be the well-known "B- style" shifting profile, for example.
- Bearing 14 contacts upper coil spring 16 and allows low- resistance rotation of the end of the spring as it is compressed or expands.
- Snap ring 17 is compressed in the radial direction in the position shown in FIG. 1 and is adapted to slide within upper spring housing 15 and once it finds the spring housing 15 lock ring profile 17a, the snap ring 17 will lock the upper flow tube 18 open.
- Seal 21 perfects a seal between housing adapter 20 and lower spring housing 25.
- Flapper 24 is supported by flapper pin 22 locked between the upper and lower flow tubes and flapper 24 is free to move along the axis of lower flow tube 29 as pressure is applied uphole (from the left side of FIG. 1) to apply a known force to shear ring or pin 30. Only a small displacement is required for shearing the ring or pin, so the ring or pin can be sheared even if a normal volume of liquid is on the low-pressure side of flapper 24.
- Flapper 24 is supported within a flapper housing 35 best shown in FIG. 5.
- Key 34 maintains upper flow tube 19 and flapper housing 35 in axial alignment and key 44 maintains lower flow tube 29 in axial alignment with the flapper housing 33.
- a shock absorbing element 33 is secured to flapper housing 35 by screws 42.
- shear ring or pin 30 is shown after shearing in the axial direction, with separation into two parts, the two parts being axially displaced, allowing flapper pin 22 and flapper 24 to move into position for opening before it has opened.
- the axial force of compressed shifting spring 26, through bearing 28 (which reduces resistance to rotation of the shifting spring) then quickly moves lower flow tube 29 downhole to make a space for opening of flapper 24.
- Flapper 24, supported by pin 22, is opened by the force of spring 16 acting on upper flow tube 18.
- Lower flow tube 29 must move rapidly enough to allow flapper 24 to fully open without interference from lower flow tube 29.
- the force of spring 26 is selected to be great enough to meet this requirement. After flapper 24 is open it is then covered in the open position by upper flow tube 18 as shown in FIG. 3.
- FIG. 3 shows flapper 24 in the open position. Note that flapper 24 has the same center of the radius of curvature in the radial plane when open as the upper flow tube 18 and lower spring housing 25. This allows open flapper 24 to be located between upper flow tube 18 and lower spring housing 25.
- Lower spring 26 has expanded in the axial direction, moving lower flow tube 29. Snap ring 17 has moved in the axial direction such that radial compression of the snap ring has caused it to move radially outward into snap ring receptor 17a. This causes upper flow tube 18 to be permanently locked in position, covering flapper 24.
- Torque stop plug 31 may be located at the distal end of lower spring housing 25 to prevent radial movement between lower sub 32 and lower spring housing 25.
- Lower spring housing 25 is joined to lower sub 32, which may be adapted to be joined to a tubular (not shown).
- FIG. 4 shows cross-section 4 identified in FIG. 1.
- Lock housing 12 is shown behind the cross-section.
- Lower spring housing 25 concentrically encloses closed flapper 24 and lower spring 26.
- Flapper pin 22 supports flapper 24, which is shown in the open position in FIG. 7.
- FIG. 5 is an isometric view of flapper 24 in a closed position with parts not shown that block the view of the flapper.
- FIG. 6 is an isometric view of the flapper in a partially open position. This view also identifies sealing surfaces 240 and 241 on the flapper shown in FIG. 8. When the flapper is closed, these surfaces mate with surfaces on upper flow tube 18 and lower flow tube 29 to form a hydraulic seal. Normally the sealing surfaces are covered with an elastomer or other type of sealing material.
- FIG. 7 is an isometric view of flapper 24 in the open position with parts not shown that block the view of the flapper.
- FIG. 8 is a perspective view of the flapper 24. Sealing surface 240 engages an end of upper flow tube 18 and sealing surface 241 engages an end of lower flow tube 29 as shown in FIG. 9.
- the mode of operation is as follows. With the flapper closed, the formation is isolated and the flapper is sandwiched between the upper and lower flow tubes, effecting a bidirectional seal above and below the flapper.
- the flapper shears a shear ring or pin or any other destructible retention mechanism via the lower flow tube which then moves axially downward.
- the destructible element 30 releases, the lower flow tube 29 moves axially downwardly by virtue of biased spring 26, thereby allowing the flapper to freely rotate to the open position.
Abstract
Description
Claims
Priority Applications (4)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
MX2017012721A MX2017012721A (en) | 2015-04-01 | 2016-01-27 | Method and apparatus for inserting a tubular string into a well. |
AU2016243210A AU2016243210A1 (en) | 2015-04-01 | 2016-01-27 | Method and apparatus for inserting a tubular string into a well |
BR112017021179A BR112017021179A2 (en) | 2015-04-01 | 2016-01-27 | isolation sub-valve for placement in a series of pipes, and method for placing a tubular wire in a well |
CA2984750A CA2984750A1 (en) | 2015-04-01 | 2016-01-27 | Method and apparatus for inserting a tubular string into a well |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US14/676,151 US20150204163A1 (en) | 2015-04-01 | 2015-04-01 | Method and Apparatus for Inserting a Tubular String into a Well |
US14/676,151 | 2015-04-01 |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2016160108A1 true WO2016160108A1 (en) | 2016-10-06 |
Family
ID=53544354
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2016/015169 WO2016160108A1 (en) | 2015-04-01 | 2016-01-27 | Method and apparatus for inserting a tubular string into a well |
Country Status (6)
Country | Link |
---|---|
US (1) | US20150204163A1 (en) |
AU (1) | AU2016243210A1 (en) |
BR (1) | BR112017021179A2 (en) |
CA (1) | CA2984750A1 (en) |
MX (1) | MX2017012721A (en) |
WO (1) | WO2016160108A1 (en) |
Families Citing this family (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US9523260B2 (en) | 2012-04-27 | 2016-12-20 | Tejas Research & Engineering, Llc | Dual barrier injection valve |
US9334709B2 (en) | 2012-04-27 | 2016-05-10 | Tejas Research & Engineering, Llc | Tubing retrievable injection valve assembly |
US10704361B2 (en) | 2012-04-27 | 2020-07-07 | Tejas Research & Engineering, Llc | Method and apparatus for injecting fluid into spaced injection zones in an oil/gas well |
US10794143B2 (en) * | 2017-10-06 | 2020-10-06 | Baker Hughes, A Ge Company, Llc | Sub-surface safety valve flapper sleeve |
Citations (7)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4399871A (en) * | 1981-12-16 | 1983-08-23 | Otis Engineering Corporation | Chemical injection valve with openable bypass |
US4619320A (en) * | 1984-03-02 | 1986-10-28 | Memory Metals, Inc. | Subsurface well safety valve and control system |
US20060118306A1 (en) * | 2003-03-28 | 2006-06-08 | Tony Laplante | Wellbore annulus flushing valve |
US20090008102A1 (en) * | 2007-07-03 | 2009-01-08 | Anderson David Z | Isolation Valve for Subsurface Safety Valve Line |
US20110067862A1 (en) * | 2009-09-18 | 2011-03-24 | Clem Nicholas J | Fracturing and Gravel Packing Tool with Multi Movement Wash Pipe Valve |
US20120085548A1 (en) * | 2010-10-06 | 2012-04-12 | Colorado School Of Mines | Downhole Tools and Methods for Selectively Accessing a Tubular Annulus of a Wellbore |
US20140034325A1 (en) * | 2012-08-03 | 2014-02-06 | Tejas Research And Engineering, Llc. | Integral Multiple Stage Safety Valves |
-
2015
- 2015-04-01 US US14/676,151 patent/US20150204163A1/en not_active Abandoned
-
2016
- 2016-01-27 AU AU2016243210A patent/AU2016243210A1/en not_active Abandoned
- 2016-01-27 MX MX2017012721A patent/MX2017012721A/en unknown
- 2016-01-27 WO PCT/US2016/015169 patent/WO2016160108A1/en active Application Filing
- 2016-01-27 BR BR112017021179A patent/BR112017021179A2/en not_active Application Discontinuation
- 2016-01-27 CA CA2984750A patent/CA2984750A1/en not_active Abandoned
Patent Citations (7)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4399871A (en) * | 1981-12-16 | 1983-08-23 | Otis Engineering Corporation | Chemical injection valve with openable bypass |
US4619320A (en) * | 1984-03-02 | 1986-10-28 | Memory Metals, Inc. | Subsurface well safety valve and control system |
US20060118306A1 (en) * | 2003-03-28 | 2006-06-08 | Tony Laplante | Wellbore annulus flushing valve |
US20090008102A1 (en) * | 2007-07-03 | 2009-01-08 | Anderson David Z | Isolation Valve for Subsurface Safety Valve Line |
US20110067862A1 (en) * | 2009-09-18 | 2011-03-24 | Clem Nicholas J | Fracturing and Gravel Packing Tool with Multi Movement Wash Pipe Valve |
US20120085548A1 (en) * | 2010-10-06 | 2012-04-12 | Colorado School Of Mines | Downhole Tools and Methods for Selectively Accessing a Tubular Annulus of a Wellbore |
US20140034325A1 (en) * | 2012-08-03 | 2014-02-06 | Tejas Research And Engineering, Llc. | Integral Multiple Stage Safety Valves |
Also Published As
Publication number | Publication date |
---|---|
MX2017012721A (en) | 2018-03-07 |
BR112017021179A2 (en) | 2018-07-03 |
CA2984750A1 (en) | 2016-10-06 |
US20150204163A1 (en) | 2015-07-23 |
AU2016243210A1 (en) | 2017-11-09 |
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