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Publication numberUS3601190 A
Publication typeGrant
Publication dateAug 24, 1971
Filing dateMay 15, 1969
Priority dateMay 15, 1969
Publication numberUS 3601190 A, US 3601190A, US-A-3601190, US3601190 A, US3601190A
InventorsMott James D
Original AssigneeBrown Oil Tools
Export CitationBiBTeX, EndNote, RefMan
External Links: USPTO, USPTO Assignment, Espacenet
Well production apparatus with fluid operated valve
US 3601190 A
Images(18)
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Description  (OCR text may contain errors)

United States Patent [72] Inventor James D. Mott Houston, Tex. {21 App]. No. 814.835 [22) Filed May 15, 1969 [451 Patented Aug. 24, 1971 (73] Assignee Brown 011 Took, Inc.

Houston, Tex.

( 54] WELL PRODUCTION APPARATUS WITH FLUID OPERATED VALVE 3 Claims, 23 Drawing P15.

[52] US. Cl 166/85, 166/87, 166/224 [51] lnt.Cl E21b33/04 {50] Fteldolsearch 166.15,.6, 75, 85-87, 95, 97, 72, 224; 251/89 [56] Refer-eons Cited UNlTED STATES PATENTS 3,007,669 11/1961 Fredd 166/72 X 3,310,107 3/1967 Yancey 166/85 X 3,411,576 11/1968 Taylor 166/.5 3,411,584 11/1968 Sizeret a1. 166/72 3,426,845 2/1969 Dollison 166/85 X 3,454,084 7/1969 Sizer 7 i 166/72 X 3,457,991 7/1969 Sizer et a1. 166/72 X Primary Examiner1an A. Calvert Attorneys-J. Vincent Martin, Joe E. Edwards and Jack R.

Springgate ABSTRACT: A well production apparatus including an improved valve adapted to be positioned in a well production string and operated responsive to a pressure fluid from the wellhead to open and close flow through the production string. The valve is positioned in the tubing hanger and is retained in open position during running by engagement with the running string.

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SHEET 15 UP 18 PATENTED AUG24 I971 SHEET 15 0F 18 A T7 Alf/5 WELL PRODUCTION APPARATUS WITH FLUID OPERATED VALVE SUMMARY The present invention relates to a well production apparatus including an improved remotely operated valve.

An object of the present invention is to provide an improved valve for a production string which is easily and positively controlled from the wellhead.

Another object is to provide an improved well string in which the production flow may be controlled from a remote position.

Still another object is to provide an improved production well string which is suitable for an underwater well and which includes a remote controlled valve for controlling the production through the production string.

Still a further object is to provide an improved remotely controlled valve for a production string which may be pulled and replaced without pulling the production tubing.

A still further object of the present invention is to provide an improved remotely controlled valve structure which may be installed on each string of dual completion well production strings to control the production flow therefrom.

BRIEF DESCRIPTION OF THE DRAWINGS These and other objects and advantages of the present invention are hereinafter set forth and explained with reference to the forms of the present invention illustrated in the drawings wherein:

FIG. I is a sectional view of the upper end of a dual production string well including the remote control tubing valve, with the strings and tubing hanger being run into a well on a running tool.

FIG. 2 is a sectional view of the structure shown in FIG. 1 illustrating the running tool being removed and showing the closing of the tubing valves.

FIG. 3 is another sectional view of the same structure illustrating the diverter plug in landed position and the tubing valves closed.

FIG. 4 is a longitudinal sectional view taken along lines 4-4 in FIG. 3 to show the control passages for the tubing valves.

FIG. 5 is a sectional view similar to FIG. 3 but showing the tubing valves in open position.

FIG. 6 is another sectional view of the well structure illustrating the removal of the tubing hanger and the tubing string.

FIG. 7 is a sectional view taken along line 77 in FIG. 1 illustrating the orienting of the tubing hanger in the body.

FIG. 8 is a sectional view taken along line 8-8 in FIG. I to illustrate the passages communicating to the tubing valves.

FIG. 9 is another sectional view taken along line 9-9 in FIG. I through the tubing valves.

FIG. 10 is a transverse sectional view taken along line 10- 10 in FIG. I showing the latching means for the tubing hanger structure.

FIG. 11 is an elevation view of the ball valve used in the present invention.

FIG. 12 is a plan view of the ball valve shown in FIG. I].

FIGS. 13A and 13B (13B being the lower extension of 13A) are sectional views of the preferred form of structure of the present invention with the tubing valves held open.

FIG. 14 is a partial sectional view of the structure shown in FIGS. [3A and 13B showing the tubing valves in closed position.

FIGS. 15A and 15B are sectional views taken along lines I5A1SA and [SB-[5B in FIGS. 13A and 13B, respectively.

FIGS. 16A and [6B are partial sectional view of the structure of the preferred form of the present invention to illustrate the control passages for the tubing valves taken along line l6l6in FIG. I9.

FIG. I7 is another sectional view to show the control passages for the tubing valves taken along line 17-17 in FIG. 19.

FIG. 18 is a transverse sectional view taken along line 18- 18in FIG. 13A.

FIG. I9 is a transverse sectional view taken along line l9- 19 in FIG. 13A.

FIGJZO is a schematic sectional view of the control system of the preferred form of the invention for the tubing valves.

DESCRIPTION OF THE PREFERRED EMBODIMENTS The structure illustrated in FIGS. 1 through 10 is a typical underwater well completion embodying the improved valve of the present invention in each of the dual production strings. This structure includes the mandrel M which supports the casing C, the dual string tubing hanger H which supports the tubing strings T, and the completion means, such as the diverter body B, which is suitably secured in the mandrel M by the latch L.

As shown in FIG. 1, the running strings R are running the tubing strings T and the tubing hanger I-I into position within the diverter body B. The remotely controlled ball valves V are mounted in the sleeves S which are slidably positioned within the bores through the tubing hanger H. The valves V are retained in open position by the running strings R during running as shown in FIG. 1 and hereinafter explained.

The ball valves V are retained between an upper seat 10 and a lower seat 12 defined in the sleeves S. The ball valves V have a generally spherical shape with a bore 14 extending through the ball valves and include a means for actuation between open and closed positions responsive to axial movement of the sleeves 5. Such actuation means includes the pins 16 which are secured in the tubing hanger H and extend through slots in the sleeve S into the grooves 18 defined in the sides of the valves V. Thus, as sleeves S and valves V move axially of the hanger H, the engagement of the pins 16 in the grooves 18 causes the ball valves V to rotate. The open or closed positions of the valves V are thus determined by the position of the sleeves S in the hanger H.

The valves V are open, i.e., their bores 14 register with the bores of the sleeves S above and below the valves, when the sleeves S are in their lowermost position with respect to tubing hanger H. The sleeves S are also biased in an upward direction by a biasing means so that the valves V are biased toward their closed position. The biasing means includes the springs 20 which surround the lower portions of sleeves S and are confined between the upwardly facing internal shoulders 22 on the tubing hanger and the downwardly facing external shoulders 24 on the sleeves S.

In running tubing strings T, it is desired that the strings remain open. As previously mentioned, the running strings R retain the valves V in open position during running by the engagement of the lower end 26 of the running strings R with the upper ends of the sleeves S. Since the strings R thread into the hanger I-l above the sleeves S, the position of the lower end 26 of strings R is preselected to engage the sleeves S and retain the sleeves S in their lowermost position against the force of the springs 20. This is clearly illustrated in FIG. I. When the tubing hanger has been landed and is latched into position in body B by the latch 28 which is seen in FIG. [0, then the running strings R are removed. The removal of the running strings R is shown in FIG. 2. As shown, the upward threading of the running strings R allows the sleeves S to move upwardly responsive to the force exerted by springs 20 closing the valves V.

Before production can be commenced. the diverter plug P is lowered into position within the diverter body B as shown in FIG. 3. The diverter plug P latches in seated position in body B and has the stingers 30 which engage within the upper end of the bores in the tubing hanger H. The lower end of the stingers 30 engage the upper end of sleeve S in its upper position but do not move the sleeve S downwardly. The diverter plug P defines the production passages 32 to the production lines 34. When the valves V are open, the production lines 34 are in communication with the interiors of their respective tubing strings T.

Patent Citations
Cited PatentFiling datePublication dateApplicantTitle
US3007669 *Sep 13, 1956Nov 7, 1961Otis Eng CoValve
US3310107 *Oct 23, 1963Mar 21, 1967Fmc CorpUnderwater well method and apparatus
US3411576 *Jul 2, 1965Nov 19, 1968Otis Eng CoWell tools
US3411584 *Jan 3, 1967Nov 19, 1968Otis Eng CoWell tools
US3426845 *Nov 29, 1965Feb 11, 1969Otis Eng CorpWell head system and method of installing the same
US3454084 *Oct 10, 1967Jul 8, 1969Otis Eng CorpWell head closure assembly
US3457991 *Feb 16, 1968Jul 29, 1969Taylor Donald F JrWell tools
Referenced by
Citing PatentFiling datePublication dateApplicantTitle
US4143712 *Jul 12, 1972Mar 13, 1979Otis Engineering CorporationApparatus for treating or completing wells
US4183404 *Nov 13, 1978Jan 15, 1980Otis Engineering CorporationPlural parallel tubing with safety joints or release from suspended receptacle
US4807700 *Sep 18, 1987Feb 28, 1989Cameron Iron Works Usa, Inc.Wireline downhole annulus valve
US5494110 *Aug 1, 1994Feb 27, 1996Alpha Thames Engineering LimitedTwo-part connector for fluid carrying conduits
US6679330 *Oct 26, 2001Jan 20, 2004Kvaerner Oilfield Products, Inc.Tubing hanger with ball valve
US6729392Feb 8, 2002May 4, 2004Dril-Quip, Inc.Tubing hanger with ball valve in the annulus bore
US7275591Sep 14, 2005Oct 2, 2007Erc IndustriesTubing hanger with ball valve in production string
US8590629 *Feb 16, 2009Nov 26, 2013Pilot Drilling Control LimitedFlow stop valve and method
US20110036591 *Feb 16, 2009Feb 17, 2011Pilot Drilling Control LimitedFlow stop valve
DE2213098A1 *Mar 17, 1972Sep 20, 1973Hydril CoDruckbetaetigtes sicherheitsventil fuer bohrlochrohrstraenge
DE2301770A1 *Jan 15, 1973Jul 18, 1974Hydril CoBohrlochvorrichtung
EP0611874A1 *Feb 1, 1994Aug 24, 1994Cooper Cameron CorporationSubsea wellhead
WO1993010327A1 *Nov 11, 1992May 27, 1993Alpha Thames EngTwo-part connector for fluid carrying conduits
WO2003038228A2 *Oct 16, 2002May 8, 2003Compton Dewey CraigTubing hanger with ball valve
WO2003067024A1 *Feb 6, 2003Aug 14, 2003Dril Quip IncTubing hanger with ball valve in the annulus bore
Classifications
U.S. Classification166/87.1, 166/322
International ClassificationE21B34/04, E21B34/00, E21B33/03, E21B33/047
Cooperative ClassificationE21B33/047, E21B34/04, E21B2034/002
European ClassificationE21B34/04, E21B33/047
Legal Events
DateCodeEventDescription
Apr 5, 1982ASAssignment
Owner name: HUGHES TOOL COMPANY A CORP. OF DE
Free format text: MERGER;ASSIGNOR:BROWN OIL TOOLS, INC. A TX CORP.;REEL/FRAME:003967/0348
Effective date: 19811214