Baker Hughes Corporation

Exxon Production Research Company

Rustom K Mody

Martin Paul Coronado

Mohan L Soni

Richard G Van Buskirk

Carl W Stoesz

Darrin Lee Willauer

Daniel R Hart

Michael J Loughlin

Michael H Johnson

Robert Joe Coon

John Lindley Baugh

Michael A Carmody

Jeffrey B Lund

Jack Thomas Oldham

Calvin J Stowe

Luis E Mendez

Albert A Mullins, Ii

Robert A Laing

Vel Berzin

James Sonnier

Robert C Smith

Roy E Swanson

Trung Quoc Huynh

Randle E Ford

David Cameron

Mark Edward Plante

Joseph P DeGeare

Lawrence Allen Sinor

James C Burtner

Greg C Badke

Mark C Solari

Floyd A Halbardier, Deceased

J Robert Bailey

Calvin Stowe, Ii

Walter Myron

Russell A Miller

Dave Stephen

Joseph P Degeare

James C Sonnier

A cutting element includes, a body having two planes, each of the two planes defining a plurality of edges, and a support extending from a first of the two planes. The support and the body are configured such that when the cutting element is resting against a planar surface such that at least one of the plurality of edges and the support are in contact with the planar surface, the second of the two planes forms an acute angle with the planar surface. Additionally, a protrusion extends laterally from at least one face of the body and an indentation is formed in at least one face of the body. The protrusion and the indentation are complementary to one another such that the protrusion of a first of the cutting elements is positionable within the indentation of a second of the cutting elements.

Cutting element, tool and method of cutting within a borehole

A vibratory tool for downhole use is capable of letting a wireline or other tools pass a passage therethrough that can be subsequently closed by landing a plug on a seat. The dump valve is disposed annularly about the central passage so that cycling the tool does not cause it to be slammed against a seat. Since only a plug is delivered to a passage the functioning parts already in the housing are made stronger to improve reliability. Additional power is delivered per stroke from modular stacked piston units. The tool can be run in a manner where the high amplitude low frequency oscillating forces are delivered to the stuck fish without impacts of the pistons on the housing.

Downhole vibratory tool

An apparatus for applying a force to a stuck object in a wellbore that includes a work string extending in the wellbore is provided. A vibrating string has a vibrator engaged with the stuck object. The vibrator drives the vibrating string to impart the force to the stuck object. An isolator associated with the work string and the vibrating string decouples a portion of a motion of the vibrating string from the work string. A method of applying a force to a stuck object in a wellbore is provided that includes comprises extending a work string in the wellbore from a surface location. A vibrating string is engaged with the stuck object. The vibrating string is driven at a frequency to apply the force to the stuck object. The work string is isolated from the vibrating string such that a portion of the motion of the vibrating string is decoupled from the work string.

Apparatus and method of applying force to a stuck object in a wellbore

A short radius exit from a window milled in casing is possible using a whipstock with a sloping surface in excess of 3.5&#xb0; and a window mill whose diameter is reduced to a percentage generally below about 95% of the casing inside diameter in a mono-bore or non-through tubing application. The system provides a greater flexibility in choosing the window location and eliminates having to penetrate adjacent formations as compared to previous techniques using a longer exit radius. The decrease in mill diameter, as compared to previous techniques, limits stresses on the milling equipment to minimize equipment failures during window milling and subsequent drilling of the lateral.

Short radius whipstock system

A method and apparatus for running a whipstock into a well bore attached to a combination mill and drill bit, releasing the mill/bit from the whipstock, milling a window in the casing, and drilling a lateral well bore, all in one trip. The mill/bit is provided with a primary cutting structure better suited for milling through the casing, and a secondary cutting structure, better suited for drilling through the earth formation. The secondary cutting structure is initially smaller in diameter than the primary cutting structure. The whipstock can be attached to the mill/bit with a shear bolt supported by a boss on the whipstock, with the boss designed to arrest axial motion of the mill/bit after shearing of the bolt.

Window mill and drill bit

A wet connect/disconnect arrangement is disclosed for a downhole system that allows installation of various tools and/or a string and subsequent electrical connection to the downhole system in a wet environment. Several embodiments are disclosed, all of which produce a clean, reliable connection. Exemplary embodiments include an upper section being mechanically and electrically joined to an intermediate section with electrical connectors for being joined at a lower section. The intermediate section further has auxiliary connectors that may be protected by a cover and remain unmated in a first connected application being therefore available for future use. The upper section may be removed leaving the intermediate section in place whereby the unmated connectors are available to rejoin a new upper section. Different types of connectors are also disclosed.

PBR with TEC bypass and wet disconnect/connect feature

An electric wireline setting tool includes a controller and a plurality of sensors sensing pressure, temperature, flow rate, current, etc. The controller communicates with the surface and or makes decisions downhole with regard to a motor and pump to tailor their activity to ensure that the tool being set is setting optimally.

Electronically controlled electric wireline setting tool

A method and apparatus are disclosed which allow isolation of a plurality of zones for treatment, particularly sand fracturing. The lowermost barrier can be pumped through tubing and anchored in cased or open holes. In the preferred embodiment, the pumped plug has a visco-elastic member which contains a particulate aggregate mixture, such as described in U.S. Pat. No. 5,417,285. The visco-elastic material is subjected to a force which changes its shape so that the material obstructs the wellbore. The shape change also accomplishes dehydration of the material within the visco-elastic enclosure by virtue of fluid displacement, resulting from a volume reduction, hardening it so that a plug using the visco-elastic material is formed. Thereafter, a packer on the tubing string is set to isolate the zone for sand fracturing. The process can be repeated without tripping out of the hole as additional plugs are pumped through tubing and the process is repeated. At the conclusion of the fracturing, the various plugs, which are of simple and economical construction, can be readily milled out.

Method and apparatus to isolate a specific zone

An inflatable packer having a sealing section, with noncontinuous ribs, is provided in combination with a ribbed element, which provides anchoring capabilities in tandem with the partially ribbed element which provides sealing capabilities in downhole applications.

Method and apparatus for hybrid element casing packer for cased-hole

A wellbore is at least partially obstructed with a partition or obstruction member. A fluid slurry of an aggregate mixture of particulate matter is pumped into the wellbore adjacent the partition or obstruction member. The aggregate mixture of particulate material contains at least one component of particulate material, and each of the at least one particulate material components has an average discrete particle dimension different from that of the other particulate material components. Fluid pressure then is applied to the aggregate material and fluid is drained from the aggregate material through a fluid drainage passage in the partition or obstruction member. The fluid pressure and drainage of fluid from the aggregate mixture combined to compact the aggregate mixture into a substantially solid, load-bearing, force-transferring, substantially fluid-impermeable plug member, which seals a first wellbore region from fluid flow communication with a second wellbore region. The plug member is easily removed from the wellbore by directing a high-pressure fluid stream toward the plug member, thereby dissolving or disintegrating the particulate material of the plug member into a fluid slurry, which may be circulated out of or suctioned from the wellbore.

Method and apparatus for sealing and transfering force in a wellbore

The invention discloses an apparatus for storing one or more constituents in a downhole tool. The constituents are segregated from each other until such time as the tool is actuated. At that time, the constituents are forced from their storage position and mixed as they are pushed from their storage position. The resultant mix is then directed to the location where the mixture will finally be placed for eventual solidification. The apparatus and method are useful for inflation of bridge plugs or external casing packers, as well as other downhole applications. Significant time is provided for the surface operator prior to initiation of the constituent elements by segregating the ingredients until shortly before they are mixed and directed to their final destination. Should a problem arise prior to mixing, the unmixed ingredients can be withdrawn from the wellbore.

Downhole mixer

A wireline tool string is provided which includes a wireline conveyable fluid-pressurization device, an equalizing apparatus, a pressure extending device, a pull-release apparatus, and a fluid-pressure actuable wellbore tool. The wireline tool string may be utilized to lower the fluid-pressure actuable wellbore tool, such as a bridge plug, through tubing string to be actuated in the wellbore below the tubing string.

Fluid-actuated wellbore tool system

A method and apparatus is provided for extending a pressurization time interval. The pressurization-extending device includes a number of components which cooperate together. The pressurization-extending device is coupled between a source of pressurized fluid, such as a pump, and a fluid-actuated wellbore tool, such as an inflatable packer or inflatable bridge plug. The components include an input for receiving pressurized fluid from the source of pressurized fluid, and an output for directing pressurized fluid to the fluid-actuated wellbore tool to supply an actuating force to the fluid-actuated wellbore tool. The pressurization-extending device further includes a timer device, which is responsive to the actuating force of the pressurized fluid, for automatically maintaining the actuating force of the pressurized fluid within the fluid-actuated wellbore tool at a preselected force level for a preselected time interval.

Method and apparatus for extending pressurization of fluid-actuated

An inflatable packing element for an inflatable packer or bridge plug utilized in subterranean wells comprises a tubular elastomeric sleeve which is surrounded by a plurality of circumferentially overlapping flexible metal ribs. The opposite ends of the ribs are respectively welded to an external surface provided on a force transmitting sleeve. The sleeve is provided with a shoulder having an abutting relationship with an internally projecting shoulder provided on the tubular mounting structure for the inflatable element.

Inflatable packing element

An inflatable packing tool is provided for use in a subterranean wellbore. The inflatable packing tool is coupled to a wellbore conduit with a central bore which directs pressurized fluid into the wellbore. The inflatable packing tool includes a central tubular body for directing fluid in the wellbore. Upper and lower stationary collar members are secured to the central tubular body for coupling the central tubular body to the wellbore conduit. An annular inflatable packing element surrounds the central tubular body, and includes a flexible fluid-tight sleeve covered by a plurality of overlapping an axially extending reinforcing ribs. A slidable sleeve assembly is coupled to one end of the annular inflatable packing element. A locking means is provided for fixing the position of the slidable sleeve assembly during a deflated running mode to prevent axial movement of the slidable sleeve assembly relative to the central tubular body, rotational movement of the slidable sleeve assembly relative to the central tubular body, and twisting of the plurality of overlapping and axially extending reinforcing ribs out of axial alignment with the central longitudinal axis of the central tubular body.

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Bellaire, TX, United States of America

Rustom K Mody