Halliburton Energy Services, Inc.

Otis Engineering Corporation

Halliburton Company

Other

Robert W Crow

William David Henderson

Ronald W McGregor

Michael B Vinzant

David A Hejl

Philip D Nguyen

John C Gano

Kenneth L Schwendemann

James R Longbottom

Travis Thomas Hailey, Jr

Pat M White

Karluf Hagen

Ronald A Gibson

Perry C Shy

Timothy Edward Harms

Michael Wade Meaders

Ricky M Holloman

Nam V Le

Nam Van Le

Steven C Speegle

Ralph Harold Jones

Robert L Hilts

Stephen Lee Crow

Cary G Mondon

James B Pruden

Gerald L LeBoeuf

A safety valve lock out system and method. In a described embodiment, a method of locking out a safety valve in a subterranean well includes the steps of: flowing a hardenable fluid into the safety valve; and preventing a closure device of the safety valve from closing with the hardenable fluid.

Safety valve lock out system and method

An apparatus () and method for treating an interval of a wellbore comprises an outer tubular () disposed within the wellbore. A sand control screen () is disposed within the outer tubular (). A treatment fluid passageway () is formed between the sand control screen () and outer tubular (). In addition, a production pathway () is formed between the sand control screen () and outer tubular (). When the apparatus () is in an operable position, the region between the outer tubular () and the wellbore serves as a primary path for delivery of a treatment fluid, the production pathway () serves as a secondary path for delivery of the treatment fluid if the primary path becomes blocked and the treatment fluid passageway () serves as a tertiary path for delivery of the treatment fluid if the primary and secondary paths become blocked.

Apparatus and method for treating an interval of a wellbore

An apparatus () and method for treating an interval of a wellbore comprises an outer tubular () disposed within the wellbore. A sand control screen () is disposed within the outer tubular (). A slurry passageway () is formed between the sand control screen () and outer tubular (). In addition, a production pathway () is formed between the sand control screen () and outer tubular (). When the apparatus () is in an operable position, the region between the outer tubular () and the wellbore serves as a primary path for delivery of a fluid slurry, the production pathway () serves as a secondary path for delivery of the fluid slurry if the primary path becomes blocked and the slurry passageway () serves as a tertiary path for delivery of the fluid slurry if the primary and secondary paths become blocked.

A gravel packing apparatus comprises multiple joints each having substantially the same construction and each having a perforated outer tubular ( ) positioned around a sand control screen ( ) including a slurry passageway ( ) and a production pathway ( ) therebetween. First and second transition members ( ) are disposed at opposite ends of each joint. When two such joints are connected together, the second transition member ( ) of one joint is proximate the first transition member ( ) of the next joint such that a fluid traveling from the slurry passageway ( ) of one joint to the slurry passageway ( ) of the next joint travels from the exterior to the interior of the second transition member ( ) of the one joint and from the interior to the exterior of the first transition member ( ) of the next joint.

Gravel packing apparatus having an integrated joint connection and method for use of same

An apparatus and method for gravel packing an interval of a wellbore comprises an outer tubular ( ), which forms a first annulus with the wellbore, and an sand control screen ( ) disposed within the outer tubular ( ) forming a second annulus therebetween. Within the second annulus is an axially extending production pathway ( ) and an axially extending slurry passageway ( ), which is defined between a sheet member ( ) positioned on the sand control screen ( ) and a channel ( ). The outer tubular ( ) has outlets ( ) that are substantially aligned with outlets ( ) of the channel ( ). When a fluid slurry containing gravel is injected through the slurry passageway ( ), the fluid slurry exits through the outlets ( ) leaving gravel in the first annulus, thereby gravel packing the interval.

Apparatus and method for gravel packing an interval of a wellbore

A seal structure is provided for a downhole tool. In a described embodiment, a seal structure includes a seal support ring having at least one annular groove formed thereon and a longitudinal axis. At least one seal is included in the seal structure. The seal is disposed at least partially in the groove, and the seal is bonded to the ring. An annular recess is positioned longitudinally between opposing side walls of the groove. The recess may be formed in a body of the seal.

Seal structure for downhole tool

A subsurface safety valve has a tubular valve housing, a valve closure member movable between an open and a closed position, an axially shiftable flow tube for opening the valve closure member. Hydraulic pressure from the control line is used to move a piston, which in turn moves an axially shiftable opening prong through the closure member. A balance line, or second hydraulic line is also used to make the valve well insensitive. An isolation valve is placed in the flow path of the second hydraulic line. The isolation valve prevents gas migration into the balance line. It also provides volume control for the fluid displaced when the piston is moved by pressure from the control line. Further, the valve can be closed by the application of sufficient pressure through the second hydraulic line.

Safety valve utilizing an isolation valve and method of using the same

A system for selective production from, and stimulation of, subterranean production zones while improving productivity and enhancing control of the well. Portions of a production tubing string and an internal stimulation/shifter string are assembled and run together as completion segments. Consecutive completion segments, with each segment including packers that surround sleeves and terminate at the upper end in a well control valve, are run into the cased wellbore so that the acid flow ports operated by sleeve valve assemblies are placed proximate the perforations of prospective production zones. The production zones are then stimulated as the stimulation/shifter string is moved progressively outward placing acid at each consecutive zone. The stimulation/shifter string is then removed from the production tubing string, mechanically closing the well control valve assembly by tubing manipulation. A well control valve assembly prevents flow from or to completion segments further downhole from the well control valve assembly once the stimulation/shifter string has been removed from the production tubing string. The well control valve assembly features a shaped flapper plate which, when opened, conforms closely to the shape and size of the production tubing string's interior diameter. The flapper plate is biased toward a closed position by a compression spring arrangement that includes an arm which levers the plate upward toward a seating surface. The valve assembly's closure is mechanically induced and is not responsive to a sensed well condition. Reopening of the valve assembly is accomplished by insertion into the assembly of a tubular member, or 'stinger', which is incorporated into a running arrangement. The stinger is described in relation to a seal assembly which is capable of reopening the well control valve and securing it in the open position. The seal assembly is incorporated into a running arrangement and inserted into the valve assembly to open the valve assembly and seal the connection between the seal assembly and the well control valve assembly.

Well completion system with well control valve

A well control valve assembly prevents flow from or to completion segments further downhole from the well control valve assembly once the stimulation stimulation/shifter string has been removed from the production tubing string. The well control valve assembly features a shaped flapper plate which, when opened, conforms closely to the shape and size of the production tubing string's interior diameter. The flapper plate is biased toward a closed position by a compression spring arrangement that includes an arm which levers the plate upward toward a seating surface. The valve assembly's closure is mechanically induced and is not responsive to a sensed well condition.

Well completion system with flapper control valve

A packer set safety valve assembly for controlling annular and tubing flows within a subterranean wellbore is disclosed. The packer set safety valve assembly controls the annular and tubing flows through dual flow paths. The assembly includes a means, that is remotely actuatable, to secure the assembly within the wellbore, a means, also remotely actuatable, the allows selective control of fluid flow in the dual flow paths, and a means, remotely actuatable as well, to unsecure the assembly from within the wellbore. The packer set safety valve assembly is a 'fail closed' design which prevents flows through the dual flow paths when the fluid flow control means is not actuated to allow flow.

Packer set safety valve for controlling dual fluid flows

A sleeve valve assembly featuring a cylindrical housing within which a sleeve valve is axially slidable within a radially expanded section of the housing. The radially expanded section of the housing presents an inwardly extending stop shoulder at one point along its length and an annular expansion notch at another point. The sleeve valve includes a radially projecting chamfered boss about its circumference. A portion of the sleeve valve is longitudinally slotted so as to form collets. An outwardly biased C-ring is disposed about the sleeve valve within the radially expanded section. The C-ring is initially disposed to be free to travel axially along the radially expanded section between the boss and the stop shoulder. As the sleeve valve is moved toward an open position, the boss, C-ring and stop shoulder engage each other such that the sleeve valve is releasably snagged against further axial movement toward the open position. A significant axial force upon the sleeve valve is required to effect unsnagging. Upon application of increased axial force, the collets of the sliding sleeve are forced radially inward to permit the boss to slip past the C-ring. An exemplary stimulation tool incorporating the sleeve valve assembly is described which permits acid to be selectively communicated into the surrounding formation. A stimulation tool constructed in accordance with the present invention is particularly useful for acid stimulation applications in horizontal well conduits as the snagging feature of the sleeve valve assembly provides a positive indication that lateral acid flow ports within the shifter tool have been placed adjacent complimentary flow ports in the surrounding housing.

Sleeve valve flow control device with locator shifter

A combination packer/safety valve assembly is connectable to the bottom end of a tubing string and lowerable therewith into the casing string portion of a gas storage well to control the upward flow through the casing string of pressurized gas stored in a subterranean cavern below the casing string. In response to the delivery through the tubing string to the interior of the assembly of control fluid at a first predetermined pressure a normally closed, axially extending interior passage of the assembly is opened to permit upward flow therethrough of pressurized gas for delivery to the well surface through the casing string. An increase of the control fluid pressure to a higher, predetermined second magnitude radially extends an anchor slip and packer structure externally carried by the assembly body into an anchored, sealing engagement with the interior surface of the casing string, and a locking structure automatically functions to hold the anchor slip and packer structure in this radially extended orientation. A subsequent increase of the control fluid pressure to a still higher, predetermined third magnitude causes the anchor slip and packer structure to be driven back to a radially retracted position, thereby releasing the assembly for upward retrieval movement with the tubing string through the casing string.

Combination packer/safety valve assembly for gas storage wells

Cheek flap for a helmet

A programmable system for controlling the operation of a plunger completion oil or gas production well to optimize production from the well. The controller operates one or more motor valves controlling the well in accordance with programmable values of off-time, on-time and exhaust-time. The controller monitors whether or not a plunger arrival signal is received on each cycle of intermitting the well and changes either the off-time or the exhaust-time for the next cycle in response thereto. In oil well mode, the off-time is decreased slightly for each cycle following a cycle in which plunger arrival occurred and increased slightly for each cycle following one in which it did not. In gas well mode, the exhaust-time is increased slightly for each cycle following a cycle in which plunger arrival occurred before on-time expired and decreased slightly for each cycle following one in which it did not.

Well production optimizing system

A protective flap for a batting helmet. The protective flap attaches to a batting helmet or is fabricated with the helmet, and extends alongside the cheek and jaw of the batter. The protective flap can attach to the ear cover of the batting helmet, and extends forwardly to an outer end approximately aligned with the front of the batter's chin or nose. The upper edge of the protective flap is spaced below the visor of the helmet to allow substantially unobstructed vision but this spacing is less than the diameter of the ball in play, to prevent the ball from striking the batter's cheek or eye.

Growing community of inventors

Irving, TX, United States of America

Robert W Crow