Halliburton Energy Services, Inc.

Other

Virgilio Garcia-Soule

Kenneth L Schwendemann

Darrin N Towers

Imre I Gazda

Jimmie R Williamson, Jr

Perry C Shy

Leo Guadalupe Collins

Timothy R Carlson

Chuck MacPhail

One embodiment of the present disclosure describes a test assembly including an inflatable packer. An internal control sleeve controls flow of drilling fluid through an inflation port to inflate and deflate the packer. A shifting tool run on a slick line moves the sleeve. The packer has one end attached to an external sliding sleeve which moves upon packer inflation to expose a formation fluid port through which formation testing is performed. After testing and packer deflation, a circulation port may be opened to recover produced fluids up the drill string. A second sleeve controls flow through the circulation port and is controlled by a second shifting tool run on slick line. Other embodiments include a circulation assembly with a sliding sleeve opened and closed by one shifting tool to control circulation and the sliding sleeve itself and its operation.

Testing drill packer

A hydraulic control system and associated methods provides selective control of operation of multiple well tool assemblies. In a described embodiment, a hydraulic control system includes a control module which has a member that is displaceable to multiple predetermined positions to thereby select from among multiple well tool assemblies for operation thereof. When the member is in a selected position, an actuator of a corresponding one of the well tool assemblies is placed in fluid communication with a flowpath connected to the control module. When the member is in another selected position, the flowpath is placed in fluid communication with an actuator of another one of the well tool assemblies.

Hydraulic control system for downhole tools

A control module system provides convenient and economical operation of downhole tools, which operation is controllable from a remote location. In a described embodiment, a control module system includes a control circuit configured to control selective opening of a plurality of valves interconnected between a plurality of accumulators and multiple tools, all positioned within the well. Additionally, the control circuit communicates with a terminal at the earth's surface for transmitting instructions from the terminal to the control circuit, and for transmitting data from the control circuit to the terminal.

Control module system for subterranean well

A subsea test tree and associated methods of servicing a well provide enhanced safety in testing operations. In a described embodiment, a subsea test tree includes a latch head assembly, a valve assembly, and a ramlock assembly interconnected between the latch head assembly and the valve assembly. The valve assembly includes two safety valves, one of which is operable by displacing a piston within the latch head assembly. The other safety valve is operable by applying fluid pressure to a line connected to the latch head assembly.

Subsea test tree and methods of servicing a subterranean well

A retainer valve provides increased safety in wellsite operations. In a preferred embodiment, operation of the retainer valve may be responsive to control line pressure or to tubing pressure. The retainer valve response is controlled by several factors, among which are relative tubing and balance line pressures, and axial positions of a number of pistons relative to a tubular J-slot member. If the control and balance lines are disconnected, or otherwise unavailable for operation of the valve, it may still be operated by manipulation of the tubing pressure at the earth's surface. Thus, the valve may be opened in emergency situations in which the control and balance lines are unavailable, but operation of the valve is still needed in order to safely relieve trapped pressure in the tubing string and/or to kill the well, unlatch a subsea test tree, etc. The retainer valve is also useful as a lubricator valve.

Normally closed retainer valve with fail-safe pump through capability

Installed in the tubing string portion of an offshore well rig are a vertically spaced pair of tubular well line protective devices. The upper device extends vertically through the openings in the rig floor and the rotary table thereon, and the lower device is positioned between a pair of sealing rams within an open upper end portion of the riser through which the tubing downwardly extends. Each protective device has a main body portion which is radially enlarged relative to the balance of the tubing string, and a removable side insert portion. Well lines, such as control, chemical and balancing lines, are extended through axial openings combinatively defined by each body and associated insert, with the insert shielding the lines from damage at the protective device location. The removable insert is illustrated in an all metal construction, used in the upper device, and an all elastomeric material construction or an elastomer-faced metal construction used in the lower device. The lower protective device is positioned between a pair of sealing rams. When the sealing rams close, the elastomeric portion of the insert portion of the lower device protects its associated well line portions from damage, and automatically creates seals around them, to block off the tubing/riser annulus and prevent leaking gas flow upwardly therethrough past the closed sealing rams. A bypass pipe structure disposed below the sealing rams diverts gas leakage outwardly past the rig when the rams are closed.

Growing community of inventors

Irving, TX, United States of America

Virgilio Garcia-Soule