Baker Hughes, a Ge Compnay, LLC

Baker Hughes Corporation

James Scott Sanchez

Jason M Harper

James G King

Justin C Kellner

Jason Charles Mailand

Edward O'Malley

Steve Rosenblatt

Juan Carlos Flores Perez

Charles C Johnson

Paul Madero

Christopher K Elliott

Robert W Putch

James T Nickles

Zhiyue Xu

YingQing Xu

Robert O'Brien

Darin Henderson Duphorne

David B Ruddock

William B Handy

Daniel S Matthews

Travis Harris

Beau Wright

André J Porter

James L Miller, Ii

Robert Pena

Dennis M Collins, Jr

Jason Coe

Maria A Avalos

Elias Pena

Wara Bocangel Calderon

Dwayne Walkoviak

Wara C Bocangel

Jeffrey D Kitzman

Daniel Matthews

Christopher Elliott

Ii Miller James L

Jason Mailand

Robert A Pena

Edward J O'malley

A bottom hole assembly (BHA) and methods of using the BHA, the BHA having at least one tool configured to move between the interior and the exterior by fluid pumped down a string. The tool is configured to create a hole in a wellbore tubular, such as casing, tubing, or a liner. The BHA includes a ramp positioned adjacent to the tool to guide the tool to engage the tubular. The tool may be a mill configured to cut a hole in the tubular or a punch member configured to punch a hole in the tubular. A packing element of the BHA enables fluid to be pumped down the annulus and through the hole to treat and/or fracture the formation. The tool may be positioned between two packing elements and fluid may be pumped down the string and through a portion of the tool to treat and/or fracture the formation.

Place-n-perf

A lock ring fits into a housing recess defined by a sliding member such as a sleeve. The lock ring is loosely fitted in the recess when the sleeve is in an initial position. The lock ring is preferably smooth on an outer dimension and has a beveled end. The beveled end engages an internal taper in the housing if a force is placed on the sliding sleeve to return it toward the original position. Preferably the shifting of the sleeve to a ports open position places the ratchet on the sleeve in alignment with the lock ring to hold the sliding sleeve locked in the open position.

Lock ring hold open device for frac sleeve

A slip-on hydraulic packer system and method. The packer system includes a tubular, a packer assembly that includes a piston moveable within a cylinder, a sealing element connected to the piston, and a biasing member connected between a stop member and the piston. Retaining elements selectively connect the packer system to an exterior surface of the tubular. A predetermined amount of hydraulic pressure may be applied to move the piston moving the sealing element from an unset position to a set position. The retaining elements may be snap rings and/or set screws that engage a profile on the tubular. Hydraulic pressure may be applied from an interior of the tubular through a port in the tubular or from an exterior of the tubular through a port in the cylinder. The predetermined amount of hydraulic pressure may shear an element or burst a member before moving the piston.

Slip-on hydraulic packer

Ported sub openings are controlled by a sliding sleeve assembly. In one variation an external sleeve is pressure actuated with internal pressure to open the ports. After the treatment the ports are closed with a ball landed on an internal sleeve seat and pressure applied from above. In a different arrangement a single internal sleeve is provided that is responsive to tubing pressure to open after breaking a retaining member. After the downhole procedure a ball is landed on a seat on the sleeve and pressure is applied to close the ports with the shifted sleeve and ball moving in tandem. Multiple sliding sleeves can be sequentially operated with sliding sleeves held by retainers that break at sequentially higher pressure moving in an uphole direction.

Hydraulically opened and ball on seat closed sliding sleeve assembly

A tubular assembly includes a turbular member having at least one opening, and a sleeve slidingly mounted relative to the tubular member. The sleeve is shiftable between an open configuration in which the at least one opening is exposed and a closed configuration in which the at least one opening is covered by the sleeve. A degradable locking member is mounted relative to one of the turbular and the sleeve. The degradable locking member selectively retains the sleeve in the open configuration. The degradable locking member is configured to degrade when exposed to a downhole fluid allowing the sleeve to be shifted to the closed configuration.

Tubular assembly including a sliding sleeve having a degradable locking element

A shifting sleeve has differential piston areas so that applied pressure displaces the sleeve against spring bias, which preferably is a series of Belleville washer stacks associated with modular mandrel components, to obtain the desired opposing force to the movement initiated with pressure applied to differential piston areas. An indexing feature is located between the sleeve and the mandrel passage wall and on a predetermined number of cycles disables the Belleville washer stacks from biasing the sleeve in an opposed direction as when pressure is applied. At this time the pressure in the mandrel acting on the differential piston area simply shifts the sleeve to open a lateral port so that fracturing through the cement that was earlier placed with the port closed can take place.

Pressure actuated ported sub for subterranean cement completions

A first sleeve is shifted with a ball landed on a seat to open treating ports. At the conclusion of the treating such as fracturing, another ball is dropped on a seat in an adjacent sleeve. The adjacent sleeve shifts to contact the initial sleeve that was shifted earlier. When the sleeves abut the treating ports are closed by the second sleeve and the production ports that are preferably screened are also opened by the shifting of the second sleeve against the first sleeve. The first sleeve hits a travel stop in the housing to produce the full open position for the treating ports. The balls can be progressively larger in a bottom up direction for the procedure or the balls can all be the same size as the landing of a ball on the first sleeve reconfigures the sleeve above for the same sized ball.

Three position interventionless treatment and production valve assembly

An intelligent dart or ball or other shape is dropped or pumped into a borehole that has multiple valves for access to the formation through which fractures are initiated. The intelligent object engages with the valves as it passes with retractable engagement dogs that are outwardly biased but not to the degree needed to find support unless the valve in question is the one that needs to be operated. In that event the dogs become supported and pressure is applied to the object to shift the valve to the open position. The object can be released at a later time remotely or can be milled out. Subsequent objects can be landed in the same sleeve after the initial object is released to close it or to close the open port by moving a second sleeve against a first sleeve. Fracturing in any order is envisioned.

Zone selection with smart object selectively operating predetermined fracturing access valves

A tubular actuation system includes a housing and an activatable sleeve including a first assembly having a first radially movable seat, a second assembly having a second radially movable seat, and an insert disposed between the first and second assemblies. The activatable sleeve is movable longitudinally from a first position to a second position, and from a second position to a third position within the housing.

Tubular actuation system and method

A tubular assembly includes a tubular having at least one opening. A slidable sleeve is slidingly mounted relative to the tubular. The slidable sleeve is shiftable between a first position, and a second position. A biasing member selectively biases the slidable sleeve in one of the first position and the second position. A degradable locking member is mounted relative to one of the tubular and the slidable sleeve. The degradable locking member selectively retains the slidable sleeve in the other of the first position and the second position. The degradable locking member is configured to degrade when exposed to a downhole fluid allowing the biasing member to shift the slidable sleeve back to the one of the first position and the second position.

A debris catcher can include an anchor connected to the wellbore tubular and a filter fixed to the anchor. The filter is positioned in a bore of the wellbore tubular and has an disintegrable accelerator material located in a carrier body. The debris catcher formed at least partially of a disintegrable accelerator material located in a carrier body is conveyed in a wellbore tubular. The disintegrable accelerator material is exposed to a downhole material in a subterranean fluid flowing through the wellbore tubular. The debris catcher filters the downhole material. It is emphasized that this abstract is provided to comply with the rules requiring an abstract, which will allow a searcher or other reader to quickly ascertain the general subject matter of the technical disclosure.

Debris catcher

A pressure test and actuation tool includes a housing; an insert disposed in operable communication with the housing. A metering head initially in sealed relation to both the housing and insert. A damper relief shoulder operably positioned relative to the metering head to initially support the metering head in sealed relationship with the housing and the insert and movable to unsupport the metering head defeating the sealed relationship with the housing and the insert. A method actuating a tool.

Pressure test and actuation tool and method

A downhole tool for performing a wellbore operation includes a perforating gun, a detector module connected to the perforating gun, wherein the detector module transmits a command in response to a signal, a signal generator configured to transmit the signal to the detector module, and a plug dropping mechanism located adjacent to the detector module, the plug dropping mechanism releasing an object upon receiving the command from the detector module. The perforating gun is fired, and the downhole tool is activated. A plug-mate positioned adjacent to the plug dropping mechanism receives the object. The plug-mate has a profile complementary to the object, and the plug-mate and the object cooperating to block flow along the wellbore. In another mode of operation, an actuation member actuates the plug-mate. It is emphasized that this abstract is provided to comply with the rules requiring an abstract, which will allow a searcher or other reader to quickly ascertain the general subject matter of the technical disclosure.

Short hop communications for a setting tool

A bridge plug with a selectively blocked flow passage is delivered on wireline and pumped down to the desired location and set. A casing pressure test can be performed above the bridge plug while shielding the formation below from excess pressure from the pressure test. To the extent there are producing zones below the bridge plug or adjacent injection wells that could communicate with the borehole, the plug isolates those pressures from below. After the pressure test is completed, a rupture disc is blown in a passage through the bridge plug and flow is then used to deliver completion equipment to a horizontal portion of the borehole and preferably on wireline.

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Tomball, TX, United States of America

James Scott Sanchez